EP2562366A2 - Method for controlling a power plant - Google Patents

Method for controlling a power plant Download PDF

Info

Publication number
EP2562366A2
EP2562366A2 EP20120180616 EP12180616A EP2562366A2 EP 2562366 A2 EP2562366 A2 EP 2562366A2 EP 20120180616 EP20120180616 EP 20120180616 EP 12180616 A EP12180616 A EP 12180616A EP 2562366 A2 EP2562366 A2 EP 2562366A2
Authority
EP
European Patent Office
Prior art keywords
slave
master
turbine
gas flow
oxygen content
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Granted
Application number
EP20120180616
Other languages
German (de)
French (fr)
Other versions
EP2562366A3 (en
EP2562366B1 (en
Inventor
Daniel David Snook
Lisa Anne Wichmann
Samuel David Draper
Noemie Dion Ouellet
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
General Electric Co
Original Assignee
General Electric Co
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by General Electric Co filed Critical General Electric Co
Publication of EP2562366A2 publication Critical patent/EP2562366A2/en
Publication of EP2562366A3 publication Critical patent/EP2562366A3/en
Application granted granted Critical
Publication of EP2562366B1 publication Critical patent/EP2562366B1/en
Active legal-status Critical Current
Anticipated expiration legal-status Critical

Links

Images

Classifications

    • FMECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F02COMBUSTION ENGINES; HOT-GAS OR COMBUSTION-PRODUCT ENGINE PLANTS
    • F02CGAS-TURBINE PLANTS; AIR INTAKES FOR JET-PROPULSION PLANTS; CONTROLLING FUEL SUPPLY IN AIR-BREATHING JET-PROPULSION PLANTS
    • F02C3/00Gas-turbine plants characterised by the use of combustion products as the working fluid
    • F02C3/34Gas-turbine plants characterised by the use of combustion products as the working fluid with recycling of part of the working fluid, i.e. semi-closed cycles with combustion products in the closed part of the cycle
    • FMECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F01MACHINES OR ENGINES IN GENERAL; ENGINE PLANTS IN GENERAL; STEAM ENGINES
    • F01DNON-POSITIVE DISPLACEMENT MACHINES OR ENGINES, e.g. STEAM TURBINES
    • F01D13/00Combinations of two or more machines or engines
    • F01D13/02Working-fluid interconnection of machines or engines
    • FMECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F02COMBUSTION ENGINES; HOT-GAS OR COMBUSTION-PRODUCT ENGINE PLANTS
    • F02CGAS-TURBINE PLANTS; AIR INTAKES FOR JET-PROPULSION PLANTS; CONTROLLING FUEL SUPPLY IN AIR-BREATHING JET-PROPULSION PLANTS
    • F02C1/00Gas-turbine plants characterised by the use of hot gases or unheated pressurised gases, as the working fluid
    • F02C1/04Gas-turbine plants characterised by the use of hot gases or unheated pressurised gases, as the working fluid the working fluid being heated indirectly
    • F02C1/08Semi-closed cycles
    • FMECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F02COMBUSTION ENGINES; HOT-GAS OR COMBUSTION-PRODUCT ENGINE PLANTS
    • F02CGAS-TURBINE PLANTS; AIR INTAKES FOR JET-PROPULSION PLANTS; CONTROLLING FUEL SUPPLY IN AIR-BREATHING JET-PROPULSION PLANTS
    • F02C6/00Plural gas-turbine plants; Combinations of gas-turbine plants with other apparatus; Adaptations of gas- turbine plants for special use
    • F02C6/04Gas-turbine plants providing heated or pressurised working fluid for other apparatus, e.g. without mechanical power output
    • F02C6/06Gas-turbine plants providing heated or pressurised working fluid for other apparatus, e.g. without mechanical power output providing compressed gas
    • F02C6/08Gas-turbine plants providing heated or pressurised working fluid for other apparatus, e.g. without mechanical power output providing compressed gas the gas being bled from the gas-turbine compressor
    • YGENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02TCLIMATE CHANGE MITIGATION TECHNOLOGIES RELATED TO TRANSPORTATION
    • Y02T50/00Aeronautics or air transport
    • Y02T50/60Efficient propulsion technologies, e.g. for aircraft

Definitions

  • the subject matter of the present disclosure relates generally to the field of electric power plants, and more particularly to methods of controlling stoichiometric exhaust gas recirculation turbine systems.
  • gas turbine systems are known and in use for electricity generation in power plants.
  • the gas turbine systems include a turbine compressor for compressing an air flow and a turbine combustor that combines the compressed air with a fuel and ignites the mixture to generate an exhaust gas.
  • the exhaust gas may then be expanded through a turbine, thereby causing the turbine to rotate, which in turn may be connected to a turbine generator via a turbine shaft, for power generation.
  • Gas turbines have traditionally used excess air within the combustion process to control turbine temperatures and manage undesirable emissions. This often results in an exhaust stream with large amounts of excess oxygen.
  • a method for controlling a stoichiometric exhaust gas recirculation power plant arrangement is provided.
  • Ambient air is compressed into a compressed ambient gas flow with at least one main air compressor.
  • At least a first portion of the compressed ambient gas flow is delivered, with a compressed ambient gas flow rate, to a turbine combustor that is fluidly connected to the at least one main air compressor.
  • a fuel stream is delivered, having a fuel stream flow rate, to the turbine combustor for mixing with the at least a first portion of the compressed ambient gas flow and with at least a first portion of a recirculated low oxygen content gas flow to form a combustible mixture.
  • the combustible mixture is burned in the turbine combustor and thereby forms the recirculated low oxygen content gas flow and drives a turbine connected to a turbine compressor via a turbine shaft.
  • At least a first portion of the recirculated low oxygen content gas flow is recirculated from the turbine to the turbine compressor using a recirculation loop.
  • the compressed ambient gas flow rate and the fuel stream flow rate are adjusted to achieve substantially stoichiometric combustion.
  • An excess portion, if any, of the at least a first portion of the compressed ambient gas flow is vented.
  • At least a second portion of the recirculated low oxygen content gas flow is extracted using an extraction conduit that is fluidly connected to the turbine compressor.
  • a method for controlling at least one master train of a stoichiometric exhaust gas recirculation power plant is provided.
  • Ambient air is compressed into a compressed ambient gas flow with at least one main air compressor.
  • At least a first portion of the compressed ambient gas flow is delivered, with a master compressed ambient gas flow rate, to a master turbine combustor that is fluidly connected to the at least one main air compressor.
  • a master fuel stream, having a master fuels stream flow rate, is delivered to the master turbine combustor for mixing with the at least a first portion of the compressed ambient gas flow and with at least a first portion of a master recirculated low oxygen content gas flow to form a master combustible mixture.
  • the master combustible mixture is burned in the master turbine combustor, thereby forming the master recirculated low oxygen content gas flow and driving a master turbine connected to a master turbine compressor via a master turbine shaft.
  • the at least a first portion of the master recirculated low oxygen content gas flow is recirculated from the master turbine to the master turbine compressor using a master recirculation loop.
  • the master compressed ambient gas flow rate and the master fuel stream flow rate are adjusted to achieve substantially stoichiometric combustion.
  • An excess portion, if any, of the at least a first portion of the compressed ambient gas flow is vented.
  • At least a second portion of the master recirculated low oxygen content gas flow is extracted using a master extraction conduit that is fluidly connected to the master turbine compressor.
  • a substantially oxygen-free exhaust stream from a gas turbine may be accomplished by stoichiometric burning in the combustion system. That is, the oxygen-containing fresh air supply may be matched to the fuel flow such that the combustion process operates substantially stoichiometrically.
  • Stoichiometric combustion may result in gas temperatures much too high for the materials and cooling technology employed in gas turbine engines. In order to reduce those high temperatures, a portion of the gas turbine exhaust products may be recirculated back to the combustion system to dilute the combustion temperatures. Ideally, this diluent gas should also be substantially oxygen-free so as to not introduce additional oxygen into the system and thereby reduce the advantages of stoichiometric combustion.
  • SEGR Stoichiometric Exhaust Gas Recirculation
  • the SEGR system may use a supply of high pressure air fed directly into the combustion process to provide the oxygen for combustion.
  • This air may be supplied by an auxiliary compressor.
  • the auxiliary compressor may allow the compressor to provide more air at times than is required by the gas turbine.
  • the auxiliary compressor may be designed with the capability to always provide more air than is required by the gas turbine. In some situations, it may be necessary to discharge some of the air compressed by the auxiliary compressor to the atmosphere.
  • embodiments of the presently disclosed subject matter may be used to control a power plant that is configured to minimize emissions by using as SEGR cycle that may enable substantially stoichiometric combustion reactions for power production.
  • the SEGR gas turbine may be configured so as to provide a low oxygen content exhaust.
  • This low oxygen content exhaust may be used with an NO x reduction catalyst to provide an exhaust stream that may also be substantially free of NO x contaminants.
  • the exhaust stream may be applied to enhanced oil recovery applications, may be ideal for carbon capture and storage (CCS) processes, or may be useful in any process where a diluent is required with a low oxygen content.
  • the present technique includes using the SEGR cycle to provide low oxygen content streams of carbon dioxide, nitrogen, and/or water.
  • the power plant arrangement 10 includes a main air compressor 12 for compressing ambient air into at least a first portion of a compressed ambient gas flow 26.
  • the power plant arrangement 10 may include a turbine combustor 32 that may be fluidly connected to the main air compressor 12.
  • the flow of the at least a first portion of the compressed ambient gas flow 26 to the turbine combustor 32 may be regulated to deliver the at least a first portion of the compressed ambient gas flow 26 with a compressed ambient gas flow rate.
  • An air injection valve 25 may also be used to control the delivery of the at least a first portion of the compressed ambient gas flow 26 to the turbine combustor.
  • An excess portion, if any, of the at least a first portion of the compressed ambient gas flow 26 may be vented to the atmosphere via a variable bleed valve 14. Such venting may be necessary, for instance, to prevent an overflow of air into the turbine compressor 32 or to prevent a buildup of backpressure into the main air compressor 12, thereby preventing a surge.
  • the turbine combustor 32 may be configured to receive the at least a first portion of the compressed ambient gas flow 26 from the main air compressor 12, at least a first portion of a recirculated low oxygen content gas flow 50 from a turbine compressor 30, and a fuel stream 28, to form a combustible mixture and to burn the combustible mixture to generate the recirculated low oxygen content gas flow 50.
  • the fuel stream 28 may be regulated by a gas control valve 27 to deliver a fuel stream flow rate.
  • the power plant arrangement 10 may comprise a turbine 34 located downstream of the turbine combustor 32.
  • the turbine 34 may be configured to expand the recirculated low oxygen content gas flow 50 and may drive an external load such as a turbine generator 20 via a turbine shaft 22 to generate electricity.
  • the main air compressor 12 and the turbine compressor 30 may be driven by the power generated by the turbine 34 via the turbine shaft 22.
  • At least a second portion of the recirculated gas flow 50 from the output of the turbine compressor 30 may be extracted through an extraction conduit 48 which may be regulated by an extraction valve 45.
  • the extraction valve 45 may be fluidly connected to a bypass conduit 49 at a point that is either upstream of or downstream from a turbine bypass valve 47.
  • the extraction conduit 48 may be fluidly connected to a gas separation system such as a carbon capture sequestration (CCS) system.
  • CCS carbon capture sequestration
  • the gas separation system may produce a stream of concentrated carbon dioxide and concentrated nitrogen, both with a low oxygen content.
  • the extraction valve 45 may be adjusted to maintain a constant mass balance in the power plant arrangement 10.
  • the term "constant mass balance" means that the system inputs, including fuel and air, are balanced with the system outputs via extraction, including carbon dioxide, nitrogen, and water.
  • the main air compressor 12 may further comprise adjustable inlet guide vanes to control the flow of air into the main air compressor 12.
  • the inlet guide vanes of the main air compressor may be used to regulate the compressed ambient gas flow rate and pressure that is delivered to the turbine combustor 32.
  • the turbine compressor 30 may further comprise adjustable inlet guide vanes to control the flow of air into the turbine compressor 30.
  • the term "recirculated low oxygen content gas flow” refers to the gas flow generated by the burning of the combustible mixture in the turbine combustor 32 and flowing through a recirculation loop 52.
  • the term “low oxygen content” refers to an oxygen content of below about 5 vol%, below about 2 vol%, or below about 1 vol%.
  • the concentration of oxygen present in the recirculated low oxygen content gas flow 50 may be detected upon exit from the turbine compressor 30 using a first oxygen sensor or upon exit from the turbine 34 using a second oxygen sensor or both.
  • gas turbine assembly refers to all listed components of the power plant arrangements except for the main air compressor 12. In embodiments comprising multiple main air compressors, the term “gas turbine assembly” refers to all listed components of the power plant arrangements except for the multiple main air compressors.
  • the recirculated low oxygen content gas flow 50 may be directed from the turbine 34 through the recirculation loop 52 to a heat recovery steam generator 36 for the generation of steam.
  • a steam turbine may be configured to generate additional electricity using the steam from the heat recovery steam generator 36, and the steam turbine may be connected to a steam generator.
  • the steam turbine may be arranged to be connected to the turbine shaft 22.
  • the recirculated low oxygen content gas flow 50 may then be directed back into the recirculation loop 52 to a recirculated gas flow cooler 40.
  • the recirculation loop 52 may not contain a heat recovery steam generator 36 and the recirculated low oxygen content gas flow 50 may instead be introduced directly into the recirculated gas flow cooler 40 upon exit from the turbine 34. In other embodiments, the recirculation loop 52 may not comprise the recirculated gas flow cooler 40.
  • the recirculated gas flow cooler 40 may be incorporated into the recirculation loop 52 anywhere downstream from the turbine 34.
  • the recirculated gas flow cooler 40 may be configured to lower the temperature of the recirculated low oxygen content gas flow 50 to a suitable temperature for downstream delivery into the turbine compressor 30 via the recirculation loop 52.
  • a suitable temperature may be below about 66 °C, below about 49 °C, or below about 45 °C.
  • the gas turbine assembly may further comprise a secondary flow path 31 that delivers at least a third portion of the recirculated low oxygen content gas flow 50 from the turbine compressor 30 to the turbine 34 as a secondary flow.
  • the secondary flow may be used to cool and seal the turbine 34, including individual components of the turbine 34 such as the turbine shroud, the turbine nozzle, the turbine blade tip, the turbine bearing support housing, and the like. After cooling and sealing the turbine 34 and any individual turbine components, the secondary flow may be directed into the recirculation loop 52 downstream of the turbine 34.
  • the exemplary power plant arrangement 10 may include a bypass conduit 49 located downstream of the turbine compressor 30 and may be in fluid connection with a portion of the recirculated gas flow 50 from the output of the turbine compressor 30.
  • a bypass flow through the bypass conduit 49 may be regulated by a turbine bypass valve 47.
  • the turbine bypass valve 47 may be used to adjust a bypass flow rate through the bypass conduit 49.
  • the bypass flow may be fluidly connected to the recirculation loop 52 downstream of the turbine 34.
  • a booster compressor 24 may be incorporated downstream of and in fluid connection with the main air compressor 12 and upstream of and in fluid connection with the turbine combustor 32.
  • the booster compressor 24 may further compress the at least a first portion of the compressed ambient gas flow 26 before delivery into the turbine combustor 32.
  • the compressed ambient gas flow rate may be varied by adjusting the speed of the booster compressor 24 and/or the inlet guide vanes of the booster compressor 24.
  • a blower 42 may be fluidly connected to the recirculation loop 52 upstream of or downstream from the recirculated gas flow cooler 40.
  • the blower 42 may be configured to increase the pressure of the recirculated low oxygen content gas flow 50 prior to delivery into the turbine compressor 30 via the recirculation loop 52.
  • an exhaust port to the atmosphere may be in fluid communication with the gas turbine assembly and may be located anywhere between an output of the turbine compressor 30 and an input of the turbine compressor 30.
  • the power plant arrangement 10 may include a damper door 38 connected to the recirculation loop 52. The damper door 38 may be opened to vent a portion of the recirculated gas flow 50 to the atmosphere.
  • the turbine shaft 22 may be a "cold-end drive” configuration, meaning the turbine shaft 22 may connect to the turbine generator 20 at the compressor end of the turbine assembly.
  • the turbine shaft 22 may be a "hot-end drive” configuration, meaning the turbine shaft 22 may connect to the turbine generator 20 at the turbine end of the turbine assembly.
  • slave is synonymous with the terms secondary, auxiliary, or additional.
  • the term “slave” refers to the second of two gas turbine assemblies, but can also mean any additional gas turbine assemblies operated with a main gas turbine assembly such as is the second gas turbine assembly in the following embodiments.
  • master train is synonymous with a master gas turbine assembly
  • slave train is synonymous with a slave gas turbine assembly.
  • the main air compressor 12 may deliver compressed ambient gas to a slave turbine combustor 72 that may be fluidly connected to the main air compressor 12 via an inter-train conduit 19.
  • the flow of the compressed ambient gas into the inter-train conduit 19 may be controlled by an air supply valve 15.
  • the flow of the compressed ambient gas through the inter-train conduit 19 may be further regulated by an inter-train valve 16 to create at least a second portion of a compressed ambient gas flow 66.
  • the at least a second portion of the compressed ambient gas flow 66 may be vented to the atmosphere via a slave variable bleed valve 18.
  • the flow of the at least a second portion of the compressed ambient gas flow 66 to a slave turbine combustor 72 may be regulated by a slave air injection valve 65 to deliver the at least a second portion of the compressed ambient gas flow 66 with a slave compressed ambient gas flow rate.
  • An excess portion, if any, of the at least a second portion of the compressed ambient gas flow 66 may be vented to the atmosphere via a slave variable bleed valve 18. Such venting may be necessary, for instance, to prevent an overflow of air into the slave turbine compressor 72 or to prevent a buildup of backpressure into the main air compressor 12, thereby preventing a surge.
  • the slave turbine combustor 72 may be configured to receive the at least a second portion of the compressed ambient gas flow 66 from the main air compressor 12, a slave recirculated gas flow 90 from a slave turbine compressor 70, and a slave fuel stream 68, to form a slave combustible mixture and to burn the slave combustible mixture to generate the slave recirculated gas flow 90.
  • the slave fuel stream 68 may be regulated by a slave gas control valve 67 to regulate a slave fuel stream flow rate.
  • the exemplary power plant arrangement 100 may include a slave turbine 74 located downstream of the slave turbine combustor 72. The slave turbine 74 may be configured to expand the slave recirculated gas flow 90 and may drive an external load such as a slave turbine generator 60 via a slave turbine shaft 62 to generate electricity.
  • the slave turbine compressor 70 may further comprise adjustable inlet guide vanes to control the flow of air into the slave turbine compressor 70.
  • At least a second portion of the slave recirculated gas flow 90 from the output of the slave turbine compressor 70 may be extracted through a slave extraction conduit 88 which may be regulated by a slave extraction valve 85.
  • the slave extraction valve 85 may be fluidly connected to the slave bypass conduit 89 at a point that is either upstream of or downstream from the slave turbine bypass valve 87.
  • the slave extraction conduit 88 may be fluidly connected to a slave gas separation system such as a carbon capture sequestration (CCS) system.
  • the slave gas separation system may produce a stream of concentrated carbon dioxide and concentrated nitrogen, both with a low oxygen content.
  • the slave extraction valve 85 may be adjusted to maintain a constant mass balance in the power plant arrangement 100.
  • constant mass balance means that the system inputs, including fuel and air, are balanced with the system outputs via extraction, including carbon dioxide, nitrogen, and water.
  • slave recirculated low oxygen content gas flow refers to the gas flow generated by burning of the slave combustible mixture in the slave turbine combustor 72 and flowing through a slave recirculation loop 92.
  • low oxygen content refers to an oxygen content of below about 5 vol%, below about 2 vol%, or below about 1 vol%.
  • the concentration of oxygen present in the slave recirculated low oxygen content gas flow 90 may be detected upon exit from the slave turbine compressor 70 using a slave first oxygen sensor or upon exit from the slave turbine 74 using a slave second oxygen sensor or both.
  • the gas turbine assembly may further comprise a slave secondary flow path 71 that may deliver a portion of the slave recirculated gas flow 90 from the slave turbine compressor 70 to the slave turbine 74 as a slave secondary flow.
  • the slave secondary flow may be used to cool and seal the slave turbine 74, including individual components of the slave turbine 74 such as the turbine shroud, the turbine nozzle, the turbine blade tip, the turbine bearing support housing, and the like. After cooling and sealing the slave turbine 74 and any individual turbine components, the slave secondary flow may be directed into the slave recirculation loop 92 near the output of the slave turbine 74.
  • the slave recirculated gas flow 90 may be directed from the slave turbine combustor 72 through the slave recirculation loop 92 to a slave heat recovery steam generator 76 for the generation of steam.
  • a slave steam turbine may be further configured to generate additional electricity using the steam from the slave heat recovery steam generator 76, and the slave steam turbine may be connected to a slave steam generator.
  • the slave heat recovery steam generator 76 may be configured to generate additional electricity when the temperature of the slave recirculated gas flow 90 is in the range from about 200 °C to about 700 °C, from about 260 °C to about 600 °C, or from about 300 °C to about 550 °C.
  • the slave steam turbine may be arranged to be connected to the slave turbine shaft 62.
  • the slave recirculated gas flow 90 may then be directed back into the slave recirculation loop 92 to a slave recirculated gas flow cooler 80.
  • the recirculation loop 92 may not contain a slave heat recovery steam generator 76 and the slave recirculated gas flow 90 may instead be introduced directly into the slave recirculated gas flow cooler 80 upon exit from the slave turbine 74.
  • the slave recirculation loop 92 may not comprise the slave recirculated gas flow cooler 80.
  • the slave recirculated gas flow cooler 80 may be incorporated into the slave recirculation loop 92 anywhere downstream of the slave turbine 74.
  • the slave recirculated gas flow cooler 80 may be configured to lower the temperature of the slave recirculated gas flow 90 to a suitable temperature for downstream delivery into the slave turbine compressor 70 via the slave recirculation loop 92.
  • a suitable temperature may be below about 66 °C, below about 49 °C, or below about 45 °C.
  • the exemplary power plant arrangement 100 may include a slave bypass conduit 89 located downstream from the slave turbine compressor 70 and may be in fluid connection with a portion of the slave recirculated gas flow 90 from the output of the slave turbine compressor 70.
  • a slave bypass flow through the slave bypass conduit 89 may be regulated by a slave turbine bypass valve 87.
  • the slave turbine bypass valve 87 may be used to adjust a slave bypass flow rate through the slave bypass conduit 89.
  • the slave bypass flow may be fluidly connected to the slave recirculation loop 92 downstream of the slave turbine 74.
  • a slave booster compressor 64 may be incorporated downstream of and in fluid connection with the main air compressor 12 and upstream of and in fluid connection with the slave turbine combustor 72.
  • the slave booster compressor 64 may further compress the at least a second portion of the compressed ambient gas flow 66 before delivery into the slave turbine combustor 72.
  • the slave compressed ambient gas flow rate may be varied by adjusting the speed of the slave booster compressor 64 and/or by adjusting the inlet guide vanes of the slave booster compressor 64.
  • a slave blower 82 may be fluidly connected to the slave recirculation loop 92 upstream of or downstream from the slave recirculated gas flow cooler 80.
  • the slave blower 82 may be configured to increase the pressure of the slave recirculated gas flow 90 prior to delivery into the slave turbine compressor 70 via the slave recirculation loop 92.
  • a slave exhaust port to the atmosphere may be in fluid communication with the slave gas turbine assembly and may be located anywhere between an output of the slave turbine compressor 70 and an input of the slave turbine compressor 70.
  • the exemplary power plant arrangement 100 may include a slave damper door 78 connected to the slave recirculation loop 92. The slave damper door 78 may be opened to vent a portion of the slave recirculated gas flow 90 to the atmosphere.
  • the slave turbine shaft 62 may be a "cold-end drive” configuration, meaning the slave turbine shaft 62 may connect to the slave turbine generator 60 at the compressor end of the salve turbine assembly.
  • the slave turbine shaft 62 may be a "hot-end drive” configuration, meaning the slave turbine shaft 62 may connect to the slave turbine generator 60 at the turbine end of the slave turbine assembly.
  • the power plant arrangement comprises one gas turbine assembly. In other embodiments, the power plant arrangement comprises two or more gas turbine assemblies that are fluidly connected by an inter-train conduit 19.
  • inter-train conduit may refer to a fluid connection between two or more gas turbine assemblies and one or more main air compressors.
  • the power plant arrangement comprises three or more gas turbine assemblies and one or more additional main air compressors, wherein the additional main air compressors are in fluid connection with each other and with the gas turbine assemblies.
  • the power plant is controllable to operate substantially stoichiometrically, meaning that the power plant arrangement is configured for substantially stoichiometric combustion.
  • the power plant arrangement may be configured for substantially zero emissions power production.
  • the master fuel stream 28 and/or the slave fuel stream 68 may comprise an organic gas, including but not limited to methane, propane, and/or butane. In still other embodiments, the master fuel stream 28 and/or the slave fuel stream 68 may comprise an organic liquid, including but not limited to methanol and/or ethanol. In yet other embodiments, the master fuel stream 28 and/or the slave fuel stream 68 may comprise a fuel source obtained from a solid carbonaceous material such as coal.
  • a control method may be used to maximize the carbon capture system extraction from a stoichiometric exhaust gas recirculation power plant.
  • maximizing extraction from the power plant may be controlled by several parameters.
  • the fuel and the compressed ambient air may be mixed and burned at the correct ratio to sustain stoichiometric combustion.
  • the content of oxygen and/or carbon dioxide products from the combustion reaction may be measured and the fuel flow rate may be fine-tuned to minimize the presence of both oxygen and carbon dioxide in the combustion reaction products.
  • the fuel flow rate and carbon capture extraction rate may be modulated to maintain a constant mass balance in the recirculation loop. This may be accomplished by pressure measurement, wherein an increase in pressure would suggest that additional extraction is needed.
  • the compressed ambient gas flow rate, the fuel flow rate, and extraction rate may be increased in proportion to maintaining the oxygen and carbon dioxide levels and system mass balance with fine adjustments to the fuel flow rate and extraction rate.
  • the compressed ambient gas flow rate, the fuel flow rate, and the extraction rate may be increased until the temperature limits of the turbine combustor, turbine, and exhaust system are reached.
  • a method for controlling a stoichiometric exhaust gas recirculation power plant arrangement 10 wherein ambient air is compressed using a main air compressor 12 to form at least a first portion of a compressed ambient gas flow 26.
  • An excess portion, if any, of the at least a first portion of the compressed ambient gas flow 26 may be vented to the atmosphere via a variable bleed valve 14.
  • At least a first portion of the compressed ambient gas flow 26, having a compressed ambient gas flow rate, may be delivered to a turbine combustor 32 that is fluidly connected to the main air compressor 12.
  • a fuel stream 28, having a fuel stream flow rate, may also be delivered to the turbine combustor 32.
  • the at least a first portion of the compressed ambient gas flow 26 may then be mixed with at least a first portion of a recirculated low oxygen content gas flow 50 and the fuel stream 28 to form a combustible mixture.
  • the combustible mixture may be burned in the turbine combustor 32 to produce the recirculated low oxygen content gas flow 50.
  • the fuel stream flow rate may be controlled by a gas control valve 27.
  • a turbine 34 may be driven using the recirculated low oxygen content gas flow 50, thereby causing the turbine 34 to rotate.
  • driven using the recirculated low oxygen content gas flow means the recirculated low oxygen content gas flow 50 expands upon exit from the turbine combustor 32 and upon entrance into the turbine 34, thereby causing the turbine 34 to rotate.
  • the rotation of the turbine 34 may cause the turbine shaft 22 and also the turbine compressor 30 to rotate.
  • the turbine shaft 22 may rotate in a turbine generator 20, such that rotation of the turbine shaft 22 may cause the turbine generator 20 to generate electricity.
  • the turbine compressor 30 may be fluidly connected to the turbine combustor 32 such that the turbine compressor 30 may compress and deliver the recirculated low oxygen content gas flow 50 to the turbine combustor 32.
  • At least a second portion of the recirculated low oxygen content gas flow 50 from the output of the turbine compressor 30 may be extracted through an extraction conduit 48 which may be regulated by an extraction valve 45.
  • the extraction valve 45 may be fluidly connected to a bypass conduit 49 at a point that is either upstream of or downstream of a turbine bypass valve 47.
  • the extraction conduit 48 may be fluidly connected to a gas separation system such as a carbon capture sequestration (CCS) system.
  • CCS carbon capture sequestration
  • the gas separation system may produce a stream of concentrated carbon dioxide and concentrated nitrogen, both with a low oxygen content.
  • the extraction valve 45 may be adjusted to maintain a constant mass balance in the power plant arrangement 10.
  • the term "constant mass balance" means that the system inputs, including fuel and air, are balanced with the system outputs via extraction, including carbon dioxide, nitrogen, and water.
  • the compressed ambient gas flow rate and the fuel stream flow rate may be adjusted to achieve substantially stoichiometric combustion.
  • substantially stoichiometric combustion means that the combustion reaction involves substantially stoichiometric burning of fuel and oxygen in the combustion system.
  • the oxygen content after the combustion reaction may be below about 5 vol%, below about 2 vol%, or below about 1 vol%.
  • the compressed ambient gas flow rate and/or the fuel stream flow rate may be adjusted based on measurements of oxygen and/or carbon dioxide present in the exhaust of the turbine 34 and/or in the recirculated low oxygen content gas flow 50.
  • the main air compressor 12 may further comprise adjustable inlet guide vanes to control the flow of air into the main air compressor 12.
  • the inlet guide vanes of the main air compressor may be used to regulate the compressed ambient gas flow rate that is delivered to the turbine combustor 32.
  • the turbine compressor 30 may further comprise adjustable inlet guide vanes to control the flow of air into the turbine compressor 30.
  • the turbine shaft 22 may be a "cold-end drive” configuration, meaning the turbine shaft 22 may connect to the turbine generator 20 at the compressor end of the turbine assembly.
  • the turbine shaft 22 may be a "hot-end drive” configuration, meaning the turbine shaft 22 may connect to the turbine generator 20 at the turbine end of the turbine assembly.
  • the term "recirculated low oxygen content gas flow” refers to the gas flow generated by the burning of the combustible mixture in the turbine combustor 32 and flowing through a recirculation loop 52.
  • the term “low oxygen content” refers to an oxygen content of below about 5 vol%, below about 2 vol%, or below about 1 vol%.
  • the concentration of oxygen present in the recirculated low oxygen content gas flow 50 may be detected, upon exit from the turbine compressor 30 using a first oxygen sensor or upon exit from the turbine 34 using a second oxygen sensor or both.
  • the recirculated low oxygen content gas flow 50 may be directed from the turbine 34 through the recirculation loop 52 to a heat recovery steam generator 36 for the generation of steam.
  • a steam turbine may be configured to generate additional electricity using the steam from the heat recovery steam generator 36, and the steam turbine may be connected to a steam generator.
  • the steam turbine may be arranged to be connected to the turbine shaft 22.
  • the recirculated low oxygen content gas flow 50 may then be directed back into the recirculation loop 52 to a recirculated gas flow cooler 40.
  • the recirculation loop 52 may not contain a heat recovery steam generator 36 and the recirculated low oxygen content gas flow 50 may instead be introduced directly into the recirculated gas flow cooler 40 upon exit from the turbine 34. In other embodiments, the recirculation loop 52 may not comprise the recirculated gas flow cooler 40.
  • the recirculated gas flow cooler 40 may be incorporated into the recirculation loop 52 anywhere downstream from the turbine 34.
  • the recirculated gas flow cooler 40 may be configured to lower the temperature of the recirculated low oxygen content gas flow 50 to a suitable temperature for downstream delivery into the turbine compressor 30 via the recirculation loop 52.
  • a suitable temperature may be below about 66 °C, below about 49 °C, or below about 45 °C.
  • At least a third portion of the recirculated low oxygen content gas flow 50 may be delivered from the turbine compressor 30 to the turbine 34 as a secondary flow.
  • the gas turbine assembly may further comprise a secondary flow path 31 that delivers at least a second portion of the recirculated low oxygen content gas flow 50 from the turbine compressor 30 to the turbine 34 as a secondary flow.
  • the secondary flow may be used to cool and seal the turbine 34, including individual components of the turbine 34 such as the turbine shroud, the turbine nozzle, the turbine blade tip, the turbine bearing support housing, and the like. After cooling and sealing the turbine 34 and any individual turbine components, the secondary flow may be directed into the recirculation loop 52 near the output of the turbine 34.
  • the turbine combustor 32 may be bypassed with at least a portion of the recirculated low oxygen content gas flow 50 using a bypass conduit 49.
  • the bypass conduit 49 may be located downstream of the turbine compressor 30 and may be in fluid connection with a portion of the recirculated gas flow 50 from the output of the turbine compressor 30.
  • a bypass flow through the bypass conduit 49 may be regulated by a turbine bypass valve 47.
  • the turbine bypass valve 47 may be used to adjust a bypass flow rate through the bypass conduit 49.
  • the bypass flow may be fluidly connected to the recirculation loop 52 downstream of the turbine 34.
  • the at least a first portion of the compressed ambient gas flow 26 may be further compressed prior to delivery into the turbine combustor 32.
  • the at least a first portion of the compressed ambient gas flow 26 may be further compressed by a booster compressor 24.
  • the booster compressor 24 may be incorporated downstream from and in fluid connection with the main air compressor 12 and upstream of an in fluid connection with the turbine combustor 32.
  • the compressed ambient gas flow rate may be varied by adjusting the speed of the booster compressor 24 and/or by adjusting the inlet guide vanes of the booster compressor 24.
  • a blower 42 may be used to increase the pressure of the recirculated low oxygen content gas flow 50.
  • the blower 42 may be fluidly connected to the recirculation loop 52 upstream of or downstream from the recirculated gas flow cooler 40.
  • the blower 42 may be configured to increase the pressure of the recirculated low oxygen content gas flow 50 prior to delivery into the turbine compressor 30 via the recirculation loop 52.
  • an excess portion, if any, of the recirculated low oxygen content gas flow 50 may be vented from the gas turbine assembly.
  • the power plant arrangement 10 may include a damper door 38 connected to the recirculation loop 52.
  • the damper door 38 may be opened to vent a portion of the recirculated low oxygen gas content flow 50 to the atmosphere.
  • master train refers to any gas turbine assembly that also includes a main air compressor.
  • slave train refers to any gas turbine assembly that does not also include a main air compressor. Thus, any given slave train requires at least one master train for operation.
  • a method for controlling at least one master train of a stoichiometric exhaust gas recirculation power plant arrangement 100 wherein ambient air is compressed using a main air compressor 12 to form at least a first portion of a compressed ambient gas flow 26.
  • an air supply valve 15 that fluidly connects the main air compressor 12 to an inter-train conduit 19 may be opened.
  • a master air injection valve 25 that fluidly connects the inter-train conduit 19 to a master turbine combustor 32 may be opened.
  • An excess portion, if any, of the at least a first portion of the compressed ambient gas flow 26 may be vented to the atmosphere via a master variable bleed valve 14.
  • At least a first portion of the compressed ambient gas flow 26, having a master compressed ambient gas flow rate, may be delivered to a master turbine combustor 32 that is fluidly connected to the main air compressor 12.
  • a master fuel stream 28, having a master fuel stream flow rate, may also be delivered to the master turbine combustor 32.
  • the at least a first portion of the compressed ambient gas flow 26 may then be mixed with at least a first portion of a master recirculated low oxygen content gas flow 50 and the master fuel stream 28 to form a master combustible mixture.
  • the master combustible mixture may be burned in the master turbine combustor 32 to produce the master recirculated low oxygen content gas flow 50.
  • the master fuel stream flow rate may be controlled by a master gas control valve 27.
  • a master turbine 34 may be driven using the master recirculated low oxygen content gas flow 50, thereby causing the master turbine 34 to rotate.
  • driven using the master recirculated low oxygen content gas flow means the master recirculated low oxygen content gas flow 50 expands upon exit from the master turbine combustor 32 and upon entrance into the master turbine 34, thereby causing the master turbine 34 to rotate.
  • the rotation of the master turbine 34 may cause the master turbine shaft 22 and also the master turbine compressor 30 to rotate.
  • the master turbine shaft 22 may rotate in a master turbine generator 20, such that rotation of the master turbine shaft 22 may cause the master turbine generator 20 to generate electricity.
  • the master turbine compressor 30 may be fluidly connected to the master turbine combustor 32 such that the master turbine compressor 30 may compress and deliver the master recirculated low oxygen content gas flow 50 to the master turbine combustor 32.
  • At least a second portion of the master recirculated gas flow 50 from the output of the master turbine compressor 30 may be extracted through a master extraction conduit 48 which may be regulated by a master extraction valve 45.
  • the master extraction valve 45 may be fluidly connected to a master bypass conduit 49 at a point that is either upstream of or downstream of a master turbine bypass valve 47.
  • the master extraction conduit 48 may be fluidly connected to a master gas separation system such as a master carbon capture sequestration (CCS) system.
  • CCS master carbon capture sequestration
  • the master gas separation system may produce a stream of concentrated carbon dioxide and concentrated nitrogen, both with a low oxygen content.
  • the master extraction valve 45 may be adjusted to maintain a constant mass balance in the master train of the power plant arrangement 100.
  • constant mass balance means that the system inputs, including fuel and air, are balanced with the system outputs via extraction, including carbon dioxide, nitrogen, and water.
  • the master compressed ambient gas flow rate and the master fuel stream flow rate may be adjusted to achieve substantially stoichiometric combustion.
  • substantially stoichiometric combustion means that the combustion reaction involves substantially stoichiometric burning of fuel and oxygen in the combustion system.
  • the oxygen content after the combustion reaction may be below about 5 vol%, below about 2 vol%, or below about 1 vol%.
  • the master compressed ambient gas flow rate and/or the master fuel stream flow rate may be adjusted based on measurements of oxygen and/or carbon dioxide present in the exhaust of the master turbine 34 and/or in the master recirculated low oxygen content gas flow 50.
  • the main air compressor 12 may further comprise adjustable inlet guide vanes to control the flow of air into the main air compressor 12.
  • the inlet guide vanes of the main air compressor may be used to regulate the compressed ambient gas flow rate that is delivered to the turbine combustor 32.
  • the master turbine compressor 30 may further comprise adjustable inlet guide vanes to control the flow of air into the master turbine compressor 30.
  • the master turbine shaft 22 may be a "cold-end drive” configuration, meaning the master turbine shaft 22 may connect to the master turbine generator 20 at the compressor end of the turbine assembly.
  • the master turbine shaft 22 may be a "hot-end drive” configuration, meaning the master turbine shaft 22 may connect to the master turbine generator 20 at the master turbine end of the turbine assembly.
  • the term "master recirculated low oxygen content gas flow” refers to the gas flow generated by the burning of the master combustible mixture in the master turbine combustor 32 and flowing through a master recirculation loop 52.
  • the term “low oxygen content” refers to an oxygen content of below about 5 vol%, below about 2 vol%, or below about 1 vol%.
  • the concentration of oxygen present in the master recirculated low oxygen content gas flow 50 may be detected, upon exit from the master turbine compressor 30 using a first master oxygen sensor or upon exit from the master turbine 34 using a second master oxygen sensor or both.
  • the master recirculated low oxygen content gas flow 50 may be directed from the master turbine 34 through the master recirculation loop 52 to a master heat recovery steam generator 36 for the generation of steam.
  • a master steam turbine may be configured to generate additional electricity using the steam from the master heat recovery steam generator 36, and the master steam turbine may be connected to a master steam generator.
  • the master steam turbine may be arranged to be connected to the master turbine shaft 22. The master recirculated low oxygen content gas flow 50 may then be directed back into the master recirculation loop 52 to a master recirculated gas flow cooler 40.
  • the master recirculation loop 52 may not contain a master heat recovery steam generator 36 and the master recirculated low oxygen content gas flow 50 may instead be introduced directly into the master recirculated gas flow cooler 40 upon exit from the master turbine 34. In other embodiments, the master recirculation loop 52 may not comprise the master recirculated gas flow cooler 40.
  • the master recirculated gas flow cooler 40 may be incorporated into the master recirculation loop 52 anywhere downstream from the master turbine 34.
  • the master recirculated gas flow cooler 40 may be configured to lower the temperature of the master recirculated low oxygen content gas flow 50 to a suitable temperature for downstream delivery into the master turbine compressor 30 via the master recirculation loop 52.
  • a suitable temperature may be below about 66 °C, below about 49 °C, or below about 45 °C.
  • At least a third portion of the master recirculated low oxygen content gas flow 50 may be delivered from the master turbine compressor 30 to the master turbine 34 as a master secondary flow.
  • the gas turbine assembly may further comprise a master secondary flow path 31 that delivers at least a third portion of the master recirculated low oxygen content gas flow 50 from the master turbine compressor 30 to the master turbine 34 as a master secondary flow.
  • the master secondary flow may be used to cool and seal the master turbine 34, including individual components of the master turbine 34 such as the turbine shroud, the turbine nozzle, the turbine blade tip, the turbine bearing support housing, and the like. After cooling and sealing the master turbine 34 and any individual turbine components, the master secondary flow may be directed into the master recirculation loop 52 near the output of the master turbine 34.
  • the master turbine combustor 32 may be bypassed with at least a portion of the master recirculated low oxygen content gas flow 50 using a master bypass conduit 49.
  • the master bypass conduit 49 may be located downstream of the master turbine compressor 30 and may be in fluid connection with a portion of the master recirculated gas flow 50 from the output of the master turbine compressor 30.
  • a master bypass flow through the master bypass conduit 49 may be regulated by a master turbine bypass valve 47.
  • the master turbine bypass valve 47 may be used to adjust a master bypass flow rate through the master bypass conduit 49.
  • the master bypass flow may be fluidly connected to the master recirculation loop 52 downstream of the master turbine 34.
  • the at least a first portion of the compressed ambient gas flow 26 may be further compressed prior to delivery into the master turbine combustor 32.
  • the at least a first portion of the compressed ambient gas flow 26 may be further compressed by a master booster compressor 24.
  • the master booster compressor 24 may be incorporated downstream from and in fluid connection with the main air compressor 12 and upstream of an in fluid connection with the master turbine combustor 32.
  • the master compressed ambient gas flow rate may be varied by adjusting the speed of the master booster compressor 24 and/or by adjusting the inlet guide vanes of the master booster compressor 24.
  • a master blower 42 may be used to increase the pressure of the master recirculated low oxygen content gas flow 50.
  • the master blower 42 may be fluidly connected to the master recirculation loop 52 upstream of or downstream of the master recirculated gas flow cooler 40.
  • the master blower 42 may be configured to increase the pressure of the master recirculated low oxygen content gas flow 50 prior to delivery into the master turbine compressor 30 via the master recirculation loop 52.
  • an excess portion, if any, of the master recirculated low oxygen content gas flow 50 may be vented from the master train.
  • the master train may include a master damper door 38 connected to the master recirculation loop 52.
  • the master damper door 38 may be opened to vent a portion of the master recirculated low oxygen gas content flow 50 to the atmosphere.
  • a method for controlling at least one slave train of a stoichiometric exhaust gas recirculation power plant arrangement 100 is provided.
  • An inter-train valve 16 may be opened, fluidly connecting the slave train to the master train.
  • a slave air injection valve 65 may be opened to fluidly connect the inter-train conduit 19 to the slave turbine combustor 72.
  • At least a second portion of the compressed ambient gas flow 66 may be delivered directly to a slave turbine combustor 72.
  • An excess portion, if any, of the at least a second portion of the compressed ambient gas flow 66 may be vented to the atmosphere via a slave variable bleed valve 18.
  • At least a second portion of the compressed ambient gas flow 66 may be delivered to a slave turbine combustor 72 that is fluidly connected to the main air compressor 12.
  • a slave fuel stream 68 having a slave fuel stream flow rate, may also be delivered to the slave turbine combustor 72.
  • the at least a second portion of the compressed ambient gas flow 66 may then be mixed with at least a first portion of a slave recirculated low oxygen content gas flow 90 and the slave fuel stream 68 to form a slave combustible mixture.
  • the slave combustible mixture may be burned in the slave turbine combustor 72 to produce the slave recirculated low oxygen content gas flow 90.
  • the slave fuel stream flow rate may be controlled by a slave gas control valve 67.
  • a slave turbine 74 may be driven using the slave recirculated low oxygen content gas flow 90, thereby causing the slave turbine 74 to rotate.
  • driven using the slave recirculated low oxygen content gas flow means the slave recirculated low oxygen content gas flow 90 expands upon exit from the slave turbine combustor 72 and upon entrance into the slave turbine 74, thereby causing the slave turbine 74 to rotate.
  • the rotation of the slave turbine 74 may cause the slave turbine shaft 62 and also the slave turbine compressor 70 to rotate.
  • the slave turbine shaft 62 may rotate in a slave turbine generator 60, such that rotation of the slave turbine shaft 62 may cause the slave turbine generator 60 to generate electricity.
  • the slave turbine compressor 70 may be fluidly connected to the slave turbine combustor 72 such that the slave turbine compressor 70 may compress and deliver the slave recirculated low oxygen content gas flow 90 to the slave turbine combustor 72.
  • At least a second portion of the slave recirculated gas flow 90 from the output of the slave turbine compressor 70 may be extracted through a slave extraction conduit 88 which may be regulated by a slave extraction valve 85.
  • the slave extraction valve 85 may be fluidly connected to a slave bypass conduit 89 at a point that is either upstream of or downstream of a slave turbine bypass valve 87.
  • the slave extraction conduit 88 may be fluidly connected to a slave gas separation system such as a slave carbon capture sequestration (CCS) system.
  • the slave gas separation system may produce a stream of concentrated carbon dioxide and concentrated nitrogen, both with a low oxygen content.
  • the slave extraction valve 85 may be adjusted to maintain a constant mass balance in the slave train of the power plant arrangement 100.
  • constant mass balance means that the system inputs, including fuel and air, are balanced with the system outputs via extraction, including carbon dioxide, nitrogen, and water.
  • the slave compressed ambient gas flow rate and the slave fuel stream flow rate may be adjusted to achieve substantially stoichiometric combustion.
  • substantially stoichiometric combustion means that the combustion reaction involves substantially stoichiometric burning of fuel and oxygen in the combustion system.
  • the oxygen content after the combustion reaction may be below about 5 vol%, below about 2 vol%, or below about 1 vol%.
  • the slave compressed ambient gas flow rate and/or the slave fuel stream flow rate may be adjusted based on measurements of oxygen and/or carbon dioxide present in the exhaust of the slave turbine 74 and/or in the slave recirculated low oxygen content gas flow 90.
  • the slave turbine compressor 70 may further comprise adjustable inlet guide vanes to control the flow of air into the slave turbine compressor 70.
  • the slave turbine shaft 62 may be a "cold-end drive” configuration, meaning the slave turbine shaft 62 may connect to the slave turbine generator 60 at the compressor end of the slave train.
  • the slave turbine shaft 62 may be a "hot-end drive” configuration, meaning the slave turbine shaft 62 may connect to the slave turbine generator 60 at the slave turbine end of the slave train.
  • slave recirculated low oxygen content gas flow refers to the gas flow generated by the burning of the slave combustible mixture in the slave turbine combustor 72 and flowing through a slave recirculation loop 92.
  • low oxygen content refers to an oxygen content of below about 5 vol%, below about 2 vol%, or below about 1 vol%.
  • the concentration of oxygen present in the slave recirculated low oxygen content gas flow 90 may be detected, upon exit from the slave turbine compressor 70 using a first slave oxygen sensor or upon exit from the slave turbine 74 using a second slave oxygen sensor or both.
  • the slave recirculated low oxygen content gas flow 90 may be directed from the slave turbine 74 through the slave recirculation loop 92 to a slave heat recovery steam generator 76 for the generation of steam.
  • a slave steam turbine may be configured to generate additional electricity using the steam from the slave heat recovery steam generator 76, and the slave steam turbine may be connected to a slave steam generator.
  • the slave steam turbine may be arranged to be connected to the slave turbine shaft 62. The slave recirculated low oxygen content gas flow 90 may then be directed back into the slave recirculation loop 92 to a slave recirculated gas flow cooler 80.
  • the slave recirculation loop 92 may not contain a slave heat recovery steam generator 76 and the slave recirculated low oxygen content gas flow 90 may instead be introduced directly into the slave recirculated gas flow cooler 80 upon exit from the slave turbine 74. In other embodiments, the slave recirculation loop 92 may not comprise the slave recirculated gas flow cooler 80.
  • the slave recirculated gas flow cooler 80 may be incorporated into the slave recirculation loop 92 anywhere downstream from the slave turbine 74.
  • the slave recirculated gas flow cooler 80 may be configured to lower the temperature of the slave recirculated low oxygen content gas flow 90 to a suitable temperature for downstream delivery into the slave turbine compressor 70 via the slave recirculation loop 92.
  • a suitable temperature may be below about 66 °C, below about 49 °C, or below about 45 °C.
  • At least a third portion of the slave recirculated low oxygen content gas flow 90 may be delivered from the slave turbine compressor 70 to the slave turbine 74 as a slave secondary flow.
  • the slave train may further comprise a slave secondary flow path 71 that delivers at least a third portion of the slave recirculated low oxygen content gas flow 90 from the slave turbine compressor 70 to the slave turbine 74 as a slave secondary flow.
  • the slave secondary flow may be used to cool and seal the slave turbine 74, including individual components of the slave turbine 74 such as the turbine shroud, the turbine nozzle, the turbine blade tip, the turbine bearing support housing, and the like. After cooling and sealing the slave turbine 74 and any individual turbine components, the slave secondary flow may be directed into the slave recirculation loop 92 near the output of the slave turbine 74.
  • the slave turbine combustor 72 may be bypassed with at least a portion of the slave recirculated low oxygen content gas flow 90 using a slave bypass conduit 89.
  • the slave bypass conduit 89 may be located downstream of the slave turbine compressor 70 and may be in fluid connection with a portion of the slave recirculated gas flow 90 from the output of the slave turbine compressor 70.
  • a slave bypass flow through the slave bypass conduit 89 may be regulated by a slave turbine bypass valve 87.
  • the slave turbine bypass valve 87 may be used to adjust a slave bypass flow rate through the slave bypass conduit 89.
  • the slave bypass flow may be fluidly connected to the slave recirculation loop 92 downstream of the slave turbine 74.
  • the at least a second portion of the compressed ambient gas flow 66 may be further compressed prior to delivery into the slave turbine combustor 72.
  • the at least a second portion of the compressed ambient gas flow 66 may be further compressed by a slave booster compressor 64.
  • the slave booster compressor 64 may be incorporated downstream from and in fluid connection with the main air compressor 12 and upstream of an in fluid connection with the slave turbine combustor 72.
  • the slave compressed ambient gas flow rate may be varied by adjusting the speed of the slave booster compressor 64 and/or the inlet guide vanes of the slave booster compressor 64.
  • a slave blower 82 may be used to increase the pressure of the slave recirculated low oxygen content gas flow 90.
  • the slave blower 82 may be fluidly connected to the slave recirculation loop 92 upstream of or downstream from the slave recirculated gas flow cooler 80.
  • the slave blower 82 may be configured to increase the pressure of the slave recirculated low oxygen content gas flow 90 prior to delivery into the slave turbine compressor 70 via the slave recirculation loop 92.
  • an excess portion, if any, of the slave recirculated low oxygen content gas flow 90 may be vented from the slave train.
  • the slave train may include a slave damper door 78 connected to the slave recirculation loop 92.
  • the slave damper door 78 may be opened to vent a portion of the slave recirculated low oxygen gas content flow 90 to the atmosphere.

Abstract

Ambient air is compressed into a compressed ambient gas flow with a main air compressor (12). The compressed ambient gas flow is delivered to a turbine combustor (32) and mixed with a fuel stream (28) and a portion of a recirculated low oxygen content gas flow (50) and is burned to form the recirculated low oxygen content gas flow (50) and drive a turbine (34). A portion of the recirculated low oxygen content gas flow (50) is recirculated from the turbine (34) to the turbine compressor (30). The compressed ambient gas flow rate and the fuel stream flow rate are adjusted to achieve substantially stoichiometric combustion. An excess portion, if any, of the compressed ambient gas flow is vented. A portion of the recirculated low oxygen content gas flow (50) is extracted using an extraction conduit (48).

Description

    BACKGROUND OF THE INVENTION
  • The subject matter of the present disclosure relates generally to the field of electric power plants, and more particularly to methods of controlling stoichiometric exhaust gas recirculation turbine systems. Various types of gas turbine systems are known and in use for electricity generation in power plants. Typically, the gas turbine systems include a turbine compressor for compressing an air flow and a turbine combustor that combines the compressed air with a fuel and ignites the mixture to generate an exhaust gas. The exhaust gas may then be expanded through a turbine, thereby causing the turbine to rotate, which in turn may be connected to a turbine generator via a turbine shaft, for power generation. Gas turbines have traditionally used excess air within the combustion process to control turbine temperatures and manage undesirable emissions. This often results in an exhaust stream with large amounts of excess oxygen.
  • Accordingly, there exists a need for a power plant arrangement that uses a gas turbine system that may operate without an exhaust stream with large amounts of excess oxygen. Furthermore, it would be desirable for the power plant arrangement to provide for the option to further reduce emissions through treatment of exhaust gases and/or to recover streams of carbon dioxide, nitrogen, and water.
  • BRIEF DESCRIPTION OF THE INVENTION
  • In one aspect, a method for controlling a stoichiometric exhaust gas recirculation power plant arrangement is provided. Ambient air is compressed into a compressed ambient gas flow with at least one main air compressor. At least a first portion of the compressed ambient gas flow is delivered, with a compressed ambient gas flow rate, to a turbine combustor that is fluidly connected to the at least one main air compressor. A fuel stream is delivered, having a fuel stream flow rate, to the turbine combustor for mixing with the at least a first portion of the compressed ambient gas flow and with at least a first portion of a recirculated low oxygen content gas flow to form a combustible mixture. The combustible mixture is burned in the turbine combustor and thereby forms the recirculated low oxygen content gas flow and drives a turbine connected to a turbine compressor via a turbine shaft. At least a first portion of the recirculated low oxygen content gas flow is recirculated from the turbine to the turbine compressor using a recirculation loop. The compressed ambient gas flow rate and the fuel stream flow rate are adjusted to achieve substantially stoichiometric combustion. An excess portion, if any, of the at least a first portion of the compressed ambient gas flow is vented. At least a second portion of the recirculated low oxygen content gas flow is extracted using an extraction conduit that is fluidly connected to the turbine compressor.
  • In another aspect, a method for controlling at least one master train of a stoichiometric exhaust gas recirculation power plant is provided. Ambient air is compressed into a compressed ambient gas flow with at least one main air compressor. At least a first portion of the compressed ambient gas flow is delivered, with a master compressed ambient gas flow rate, to a master turbine combustor that is fluidly connected to the at least one main air compressor. A master fuel stream, having a master fuels stream flow rate, is delivered to the master turbine combustor for mixing with the at least a first portion of the compressed ambient gas flow and with at least a first portion of a master recirculated low oxygen content gas flow to form a master combustible mixture. The master combustible mixture is burned in the master turbine combustor, thereby forming the master recirculated low oxygen content gas flow and driving a master turbine connected to a master turbine compressor via a master turbine shaft. The at least a first portion of the master recirculated low oxygen content gas flow is recirculated from the master turbine to the master turbine compressor using a master recirculation loop. The master compressed ambient gas flow rate and the master fuel stream flow rate are adjusted to achieve substantially stoichiometric combustion. An excess portion, if any, of the at least a first portion of the compressed ambient gas flow is vented. At least a second portion of the master recirculated low oxygen content gas flow is extracted using a master extraction conduit that is fluidly connected to the master turbine compressor.
  • Additional aspects will be set forth in part in the description that follows, and in part will be obvious from the description, or may be learned by practice of the aspects described below. The advantages described below will be realized and attained by means of the elements and combinations particularly pointed out in the appended claims. It is to be understood that both the foregoing general description and the following detailed description are exemplary and explanatory only and are not restrictive.
  • BRIEF DESCRIPTION OF THE DRAWINGS
  • These and other features, aspects, and advantages of the present invention will become better understood when the following detailed description is read with reference to the accompanying drawings, where the components are not necessarily to scale, and in which corresponding reference numerals designate corresponding parts throughout the drawings, wherein:
    • FIG. 1 is a diagrammatical illustration of an exemplary power plant arrangement 10 in accordance with an embodiment of the present invention.
    • FIG. 2 is diagrammatical illustration of another exemplary power plant arrangement 100 in accordance with an embodiment of the present invention.
    DETAILED DESCRIPTION OF THE INVENTION
  • In the following description, numerous specific details are given to provide a thorough understanding of embodiments. The embodiments can be practiced without one or more of the specific details, or with other methods, components, materials, etc. In other instances, well-known structures, materials, or operations are not shown or described in detail to avoid obscuring aspects of the embodiments.
  • Reference throughout this specification to "one embodiment," "an embodiment," or "embodiments" means that a particular feature, structure, or characteristic described in connection with the embodiment is included in at least one embodiment. Thus, the appearances of the phrases "in one embodiment" or "in an embodiment" in various places throughout this specification are not necessarily all referring to the same embodiment. Furthermore, the particular features, structures, or characteristics may be combined in any suitable manner in one or more embodiments.
  • Recent requirements in the power generation industry have necessitated the development of a gas turbine arrangement that may be configured to consume almost all of the oxygen in the air working fluid to produce a substantially oxygen-free exhaust stream. Such an exhaust stream may be more easily suited to emissions reductions using NOx catalysts. Additionally, such an exhaust stream may be better suited to post combustion carbon capture solutions due to the low oxygen concentrations. Furthermore, an essentially oxygen-free exhaust stream may be more easily suited to enhanced oil recovery applications.
  • A substantially oxygen-free exhaust stream from a gas turbine may be accomplished by stoichiometric burning in the combustion system. That is, the oxygen-containing fresh air supply may be matched to the fuel flow such that the combustion process operates substantially stoichiometrically.
  • A stoichiometric combustion reaction of methane and oxygen is illustrated below:

             CH4 + 2 O2 → CO2 + 2 H2O

  • Stoichiometric combustion may result in gas temperatures much too high for the materials and cooling technology employed in gas turbine engines. In order to reduce those high temperatures, a portion of the gas turbine exhaust products may be recirculated back to the combustion system to dilute the combustion temperatures. Ideally, this diluent gas should also be substantially oxygen-free so as to not introduce additional oxygen into the system and thereby reduce the advantages of stoichiometric combustion. The gas turbine application using stoichiometric combustion and recirculated exhaust gas is referred to as Stoichiometric Exhaust Gas Recirculation (SEGR).
  • The SEGR system may use a supply of high pressure air fed directly into the combustion process to provide the oxygen for combustion. This air may be supplied by an auxiliary compressor. In practice, the ability of an auxiliary compressor to provide air at the pressure and flow rate required by the SEGR gas turbine will not be matched across all operating ranges of load and ambient temperature experienced by the system. The auxiliary compressor may allow the compressor to provide more air at times than is required by the gas turbine. Further, the auxiliary compressor may be designed with the capability to always provide more air than is required by the gas turbine. In some situations, it may be necessary to discharge some of the air compressed by the auxiliary compressor to the atmosphere.
  • As discussed in detail below, embodiments of the presently disclosed subject matter may be used to control a power plant that is configured to minimize emissions by using as SEGR cycle that may enable substantially stoichiometric combustion reactions for power production. The SEGR gas turbine may be configured so as to provide a low oxygen content exhaust. This low oxygen content exhaust may be used with an NOx reduction catalyst to provide an exhaust stream that may also be substantially free of NOx contaminants. The exhaust stream may be applied to enhanced oil recovery applications, may be ideal for carbon capture and storage (CCS) processes, or may be useful in any process where a diluent is required with a low oxygen content. In some of the specific embodiments, the present technique includes using the SEGR cycle to provide low oxygen content streams of carbon dioxide, nitrogen, and/or water.
  • Power Plant Arrangements
  • Turning now to the drawings and referring first to FIG. 1 a power plant arrangement 10 is illustrated. The power plant arrangement 10 includes a main air compressor 12 for compressing ambient air into at least a first portion of a compressed ambient gas flow 26. The power plant arrangement 10 may include a turbine combustor 32 that may be fluidly connected to the main air compressor 12. The flow of the at least a first portion of the compressed ambient gas flow 26 to the turbine combustor 32 may be regulated to deliver the at least a first portion of the compressed ambient gas flow 26 with a compressed ambient gas flow rate. An air injection valve 25 may also be used to control the delivery of the at least a first portion of the compressed ambient gas flow 26 to the turbine combustor.
  • An excess portion, if any, of the at least a first portion of the compressed ambient gas flow 26 may be vented to the atmosphere via a variable bleed valve 14. Such venting may be necessary, for instance, to prevent an overflow of air into the turbine compressor 32 or to prevent a buildup of backpressure into the main air compressor 12, thereby preventing a surge.
  • The turbine combustor 32 may be configured to receive the at least a first portion of the compressed ambient gas flow 26 from the main air compressor 12, at least a first portion of a recirculated low oxygen content gas flow 50 from a turbine compressor 30, and a fuel stream 28, to form a combustible mixture and to burn the combustible mixture to generate the recirculated low oxygen content gas flow 50. In some embodiments, the fuel stream 28 may be regulated by a gas control valve 27 to deliver a fuel stream flow rate.
  • In addition, the power plant arrangement 10 may comprise a turbine 34 located downstream of the turbine combustor 32. The turbine 34 may be configured to expand the recirculated low oxygen content gas flow 50 and may drive an external load such as a turbine generator 20 via a turbine shaft 22 to generate electricity. In the illustrated embodiment 10, the main air compressor 12 and the turbine compressor 30 may be driven by the power generated by the turbine 34 via the turbine shaft 22.
  • At least a second portion of the recirculated gas flow 50 from the output of the turbine compressor 30 may be extracted through an extraction conduit 48 which may be regulated by an extraction valve 45. In some embodiments, the extraction valve 45 may be fluidly connected to a bypass conduit 49 at a point that is either upstream of or downstream from a turbine bypass valve 47. In some embodiments, the extraction conduit 48 may be fluidly connected to a gas separation system such as a carbon capture sequestration (CCS) system. In still other embodiments, the gas separation system may produce a stream of concentrated carbon dioxide and concentrated nitrogen, both with a low oxygen content. In some embodiments, the extraction valve 45 may be adjusted to maintain a constant mass balance in the power plant arrangement 10. As used herein, the term "constant mass balance" means that the system inputs, including fuel and air, are balanced with the system outputs via extraction, including carbon dioxide, nitrogen, and water.
  • In some embodiments, the main air compressor 12 may further comprise adjustable inlet guide vanes to control the flow of air into the main air compressor 12. The inlet guide vanes of the main air compressor may be used to regulate the compressed ambient gas flow rate and pressure that is delivered to the turbine combustor 32. In some embodiments, the turbine compressor 30 may further comprise adjustable inlet guide vanes to control the flow of air into the turbine compressor 30.
  • As used herein, the term "recirculated low oxygen content gas flow" refers to the gas flow generated by the burning of the combustible mixture in the turbine combustor 32 and flowing through a recirculation loop 52. In some embodiments, the term "low oxygen content" refers to an oxygen content of below about 5 vol%, below about 2 vol%, or below about 1 vol%. The concentration of oxygen present in the recirculated low oxygen content gas flow 50 may be detected upon exit from the turbine compressor 30 using a first oxygen sensor or upon exit from the turbine 34 using a second oxygen sensor or both.
  • As used herein, the term "gas turbine assembly" refers to all listed components of the power plant arrangements except for the main air compressor 12. In embodiments comprising multiple main air compressors, the term "gas turbine assembly" refers to all listed components of the power plant arrangements except for the multiple main air compressors.
  • In some embodiments, the recirculated low oxygen content gas flow 50 may be directed from the turbine 34 through the recirculation loop 52 to a heat recovery steam generator 36 for the generation of steam. A steam turbine may be configured to generate additional electricity using the steam from the heat recovery steam generator 36, and the steam turbine may be connected to a steam generator. In some embodiments, the steam turbine may be arranged to be connected to the turbine shaft 22. The recirculated low oxygen content gas flow 50 may then be directed back into the recirculation loop 52 to a recirculated gas flow cooler 40. In still other embodiments, the recirculation loop 52 may not contain a heat recovery steam generator 36 and the recirculated low oxygen content gas flow 50 may instead be introduced directly into the recirculated gas flow cooler 40 upon exit from the turbine 34. In other embodiments, the recirculation loop 52 may not comprise the recirculated gas flow cooler 40.
  • The recirculated gas flow cooler 40 may be incorporated into the recirculation loop 52 anywhere downstream from the turbine 34. The recirculated gas flow cooler 40 may be configured to lower the temperature of the recirculated low oxygen content gas flow 50 to a suitable temperature for downstream delivery into the turbine compressor 30 via the recirculation loop 52. In some embodiments, a suitable temperature may be below about 66 °C, below about 49 °C, or below about 45 °C.
  • In some embodiments, the gas turbine assembly may further comprise a secondary flow path 31 that delivers at least a third portion of the recirculated low oxygen content gas flow 50 from the turbine compressor 30 to the turbine 34 as a secondary flow. The secondary flow may be used to cool and seal the turbine 34, including individual components of the turbine 34 such as the turbine shroud, the turbine nozzle, the turbine blade tip, the turbine bearing support housing, and the like. After cooling and sealing the turbine 34 and any individual turbine components, the secondary flow may be directed into the recirculation loop 52 downstream of the turbine 34.
  • In some embodiments, the exemplary power plant arrangement 10 may include a bypass conduit 49 located downstream of the turbine compressor 30 and may be in fluid connection with a portion of the recirculated gas flow 50 from the output of the turbine compressor 30. In some embodiments, a bypass flow through the bypass conduit 49 may be regulated by a turbine bypass valve 47. The turbine bypass valve 47 may be used to adjust a bypass flow rate through the bypass conduit 49. In some embodiments, the bypass flow may be fluidly connected to the recirculation loop 52 downstream of the turbine 34.
  • In some embodiments, a booster compressor 24 may be incorporated downstream of and in fluid connection with the main air compressor 12 and upstream of and in fluid connection with the turbine combustor 32. The booster compressor 24 may further compress the at least a first portion of the compressed ambient gas flow 26 before delivery into the turbine combustor 32. In some embodiments, the compressed ambient gas flow rate may be varied by adjusting the speed of the booster compressor 24 and/or the inlet guide vanes of the booster compressor 24.
  • In still other embodiments, a blower 42 may be fluidly connected to the recirculation loop 52 upstream of or downstream from the recirculated gas flow cooler 40. The blower 42 may be configured to increase the pressure of the recirculated low oxygen content gas flow 50 prior to delivery into the turbine compressor 30 via the recirculation loop 52.
  • In some embodiments, an exhaust port to the atmosphere may be in fluid communication with the gas turbine assembly and may be located anywhere between an output of the turbine compressor 30 and an input of the turbine compressor 30. In some embodiments, the power plant arrangement 10 may include a damper door 38 connected to the recirculation loop 52. The damper door 38 may be opened to vent a portion of the recirculated gas flow 50 to the atmosphere.
  • As illustrated by FIG. 1, in some embodiments, the turbine shaft 22 may be a "cold-end drive" configuration, meaning the turbine shaft 22 may connect to the turbine generator 20 at the compressor end of the turbine assembly. In other embodiments, the turbine shaft 22 may be a "hot-end drive" configuration, meaning the turbine shaft 22 may connect to the turbine generator 20 at the turbine end of the turbine assembly.
  • As used herein, the term "slave" is synonymous with the terms secondary, auxiliary, or additional. In the following embodiments, the term "slave" refers to the second of two gas turbine assemblies, but can also mean any additional gas turbine assemblies operated with a main gas turbine assembly such as is the second gas turbine assembly in the following embodiments. Furthermore, the term "master train" is synonymous with a master gas turbine assembly, while the term "slave train" is synonymous with a slave gas turbine assembly.
  • As illustrated in FIG. 2, in some embodiments, the main air compressor 12 may deliver compressed ambient gas to a slave turbine combustor 72 that may be fluidly connected to the main air compressor 12 via an inter-train conduit 19. In some embodiments, the flow of the compressed ambient gas into the inter-train conduit 19 may be controlled by an air supply valve 15. The flow of the compressed ambient gas through the inter-train conduit 19 may be further regulated by an inter-train valve 16 to create at least a second portion of a compressed ambient gas flow 66. In some embodiments, the at least a second portion of the compressed ambient gas flow 66 may be vented to the atmosphere via a slave variable bleed valve 18. In some embodiments, the flow of the at least a second portion of the compressed ambient gas flow 66 to a slave turbine combustor 72 may be regulated by a slave air injection valve 65 to deliver the at least a second portion of the compressed ambient gas flow 66 with a slave compressed ambient gas flow rate.
  • An excess portion, if any, of the at least a second portion of the compressed ambient gas flow 66 may be vented to the atmosphere via a slave variable bleed valve 18. Such venting may be necessary, for instance, to prevent an overflow of air into the slave turbine compressor 72 or to prevent a buildup of backpressure into the main air compressor 12, thereby preventing a surge.
  • The slave turbine combustor 72 may be configured to receive the at least a second portion of the compressed ambient gas flow 66 from the main air compressor 12, a slave recirculated gas flow 90 from a slave turbine compressor 70, and a slave fuel stream 68, to form a slave combustible mixture and to burn the slave combustible mixture to generate the slave recirculated gas flow 90. In some embodiments, the slave fuel stream 68 may be regulated by a slave gas control valve 67 to regulate a slave fuel stream flow rate. In addition, the exemplary power plant arrangement 100 may include a slave turbine 74 located downstream of the slave turbine combustor 72. The slave turbine 74 may be configured to expand the slave recirculated gas flow 90 and may drive an external load such as a slave turbine generator 60 via a slave turbine shaft 62 to generate electricity.
  • In some emodiments, the slave turbine compressor 70 may further comprise adjustable inlet guide vanes to control the flow of air into the slave turbine compressor 70.
  • At least a second portion of the slave recirculated gas flow 90 from the output of the slave turbine compressor 70 may be extracted through a slave extraction conduit 88 which may be regulated by a slave extraction valve 85. In some embodiments, the slave extraction valve 85 may be fluidly connected to the slave bypass conduit 89 at a point that is either upstream of or downstream from the slave turbine bypass valve 87.
  • In some embodiments, the slave extraction conduit 88 may be fluidly connected to a slave gas separation system such as a carbon capture sequestration (CCS) system. In still other embodiments, the slave gas separation system may produce a stream of concentrated carbon dioxide and concentrated nitrogen, both with a low oxygen content. In some embodiments, the slave extraction valve 85 may be adjusted to maintain a constant mass balance in the power plant arrangement 100. As used herein, the term "constant mass balance" means that the system inputs, including fuel and air, are balanced with the system outputs via extraction, including carbon dioxide, nitrogen, and water.
  • As used herein, the term "slave recirculated low oxygen content gas flow" refers to the gas flow generated by burning of the slave combustible mixture in the slave turbine combustor 72 and flowing through a slave recirculation loop 92. As used herein, the term "low oxygen content" refers to an oxygen content of below about 5 vol%, below about 2 vol%, or below about 1 vol%. The concentration of oxygen present in the slave recirculated low oxygen content gas flow 90 may be detected upon exit from the slave turbine compressor 70 using a slave first oxygen sensor or upon exit from the slave turbine 74 using a slave second oxygen sensor or both.
  • In some embodiments, the gas turbine assembly may further comprise a slave secondary flow path 71 that may deliver a portion of the slave recirculated gas flow 90 from the slave turbine compressor 70 to the slave turbine 74 as a slave secondary flow. The slave secondary flow may be used to cool and seal the slave turbine 74, including individual components of the slave turbine 74 such as the turbine shroud, the turbine nozzle, the turbine blade tip, the turbine bearing support housing, and the like. After cooling and sealing the slave turbine 74 and any individual turbine components, the slave secondary flow may be directed into the slave recirculation loop 92 near the output of the slave turbine 74.
  • In some embodiments, the slave recirculated gas flow 90 may be directed from the slave turbine combustor 72 through the slave recirculation loop 92 to a slave heat recovery steam generator 76 for the generation of steam. A slave steam turbine may be further configured to generate additional electricity using the steam from the slave heat recovery steam generator 76, and the slave steam turbine may be connected to a slave steam generator. In some embodiments, the slave heat recovery steam generator 76 may be configured to generate additional electricity when the temperature of the slave recirculated gas flow 90 is in the range from about 200 °C to about 700 °C, from about 260 °C to about 600 °C, or from about 300 °C to about 550 °C. In some embodiments, the slave steam turbine may be arranged to be connected to the slave turbine shaft 62. The slave recirculated gas flow 90 may then be directed back into the slave recirculation loop 92 to a slave recirculated gas flow cooler 80. In still other embodiments, the recirculation loop 92 may not contain a slave heat recovery steam generator 76 and the slave recirculated gas flow 90 may instead be introduced directly into the slave recirculated gas flow cooler 80 upon exit from the slave turbine 74. In other embodiments, the slave recirculation loop 92 may not comprise the slave recirculated gas flow cooler 80.
  • The slave recirculated gas flow cooler 80 may be incorporated into the slave recirculation loop 92 anywhere downstream of the slave turbine 74. The slave recirculated gas flow cooler 80 may be configured to lower the temperature of the slave recirculated gas flow 90 to a suitable temperature for downstream delivery into the slave turbine compressor 70 via the slave recirculation loop 92. In some embodiments, a suitable temperature may be below about 66 °C, below about 49 °C, or below about 45 °C.
  • In some embodiments, the exemplary power plant arrangement 100 may include a slave bypass conduit 89 located downstream from the slave turbine compressor 70 and may be in fluid connection with a portion of the slave recirculated gas flow 90 from the output of the slave turbine compressor 70. In some embodiments, a slave bypass flow through the slave bypass conduit 89 may be regulated by a slave turbine bypass valve 87. The slave turbine bypass valve 87 may be used to adjust a slave bypass flow rate through the slave bypass conduit 89. In some embodiments, the slave bypass flow may be fluidly connected to the slave recirculation loop 92 downstream of the slave turbine 74.
  • In some embodiments, a slave booster compressor 64 may be incorporated downstream of and in fluid connection with the main air compressor 12 and upstream of and in fluid connection with the slave turbine combustor 72. The slave booster compressor 64 may further compress the at least a second portion of the compressed ambient gas flow 66 before delivery into the slave turbine combustor 72. In some embodiments, the slave compressed ambient gas flow rate may be varied by adjusting the speed of the slave booster compressor 64 and/or by adjusting the inlet guide vanes of the slave booster compressor 64.
  • In some embodiments, a slave blower 82 may be fluidly connected to the slave recirculation loop 92 upstream of or downstream from the slave recirculated gas flow cooler 80. The slave blower 82 may be configured to increase the pressure of the slave recirculated gas flow 90 prior to delivery into the slave turbine compressor 70 via the slave recirculation loop 92.
  • In some embodiments, a slave exhaust port to the atmosphere may be in fluid communication with the slave gas turbine assembly and may be located anywhere between an output of the slave turbine compressor 70 and an input of the slave turbine compressor 70. In some embodiments, the exemplary power plant arrangement 100 may include a slave damper door 78 connected to the slave recirculation loop 92. The slave damper door 78 may be opened to vent a portion of the slave recirculated gas flow 90 to the atmosphere.
  • As illustrated by FIG. 2, in some embodiments, the slave turbine shaft 62 may be a "cold-end drive" configuration, meaning the slave turbine shaft 62 may connect to the slave turbine generator 60 at the compressor end of the salve turbine assembly. In other embodiments, the slave turbine shaft 62 may be a "hot-end drive" configuration, meaning the slave turbine shaft 62 may connect to the slave turbine generator 60 at the turbine end of the slave turbine assembly.
  • In some embodiments, the power plant arrangement comprises one gas turbine assembly. In other embodiments, the power plant arrangement comprises two or more gas turbine assemblies that are fluidly connected by an inter-train conduit 19. As used herein, the term "inter-train conduit" may refer to a fluid connection between two or more gas turbine assemblies and one or more main air compressors. In still other embodiments, the power plant arrangement comprises three or more gas turbine assemblies and one or more additional main air compressors, wherein the additional main air compressors are in fluid connection with each other and with the gas turbine assemblies. In some embodiments, the power plant is controllable to operate substantially stoichiometrically, meaning that the power plant arrangement is configured for substantially stoichiometric combustion. In still other embodiments, the power plant arrangement may be configured for substantially zero emissions power production.
  • In some embodiments, the master fuel stream 28 and/or the slave fuel stream 68 may comprise an organic gas, including but not limited to methane, propane, and/or butane. In still other embodiments, the master fuel stream 28 and/or the slave fuel stream 68 may comprise an organic liquid, including but not limited to methanol and/or ethanol. In yet other embodiments, the master fuel stream 28 and/or the slave fuel stream 68 may comprise a fuel source obtained from a solid carbonaceous material such as coal.
  • Control Method
  • A control method may be used to maximize the carbon capture system extraction from a stoichiometric exhaust gas recirculation power plant. At a high level, maximizing extraction from the power plant may be controlled by several parameters. The fuel and the compressed ambient air may be mixed and burned at the correct ratio to sustain stoichiometric combustion. The content of oxygen and/or carbon dioxide products from the combustion reaction may be measured and the fuel flow rate may be fine-tuned to minimize the presence of both oxygen and carbon dioxide in the combustion reaction products. The fuel flow rate and carbon capture extraction rate may be modulated to maintain a constant mass balance in the recirculation loop. This may be accomplished by pressure measurement, wherein an increase in pressure would suggest that additional extraction is needed. Once the oxygen and carbon dioxide levels are at a minimum and the system mass balance is stable, then the compressed ambient gas flow rate, the fuel flow rate, and extraction rate may be increased in proportion to maintaining the oxygen and carbon dioxide levels and system mass balance with fine adjustments to the fuel flow rate and extraction rate. Ideally, the compressed ambient gas flow rate, the fuel flow rate, and the extraction rate may be increased until the temperature limits of the turbine combustor, turbine, and exhaust system are reached.
  • In operation, a method for controlling a stoichiometric exhaust gas recirculation power plant arrangement 10 is provided, wherein ambient air is compressed using a main air compressor 12 to form at least a first portion of a compressed ambient gas flow 26. An excess portion, if any, of the at least a first portion of the compressed ambient gas flow 26 may be vented to the atmosphere via a variable bleed valve 14.
  • At least a first portion of the compressed ambient gas flow 26, having a compressed ambient gas flow rate, may be delivered to a turbine combustor 32 that is fluidly connected to the main air compressor 12. A fuel stream 28, having a fuel stream flow rate, may also be delivered to the turbine combustor 32. The at least a first portion of the compressed ambient gas flow 26 may then be mixed with at least a first portion of a recirculated low oxygen content gas flow 50 and the fuel stream 28 to form a combustible mixture. The combustible mixture may be burned in the turbine combustor 32 to produce the recirculated low oxygen content gas flow 50. In some embodiments, the fuel stream flow rate may be controlled by a gas control valve 27.
  • A turbine 34 may be driven using the recirculated low oxygen content gas flow 50, thereby causing the turbine 34 to rotate. As used herein, the term "driven using the recirculated low oxygen content gas flow" means the recirculated low oxygen content gas flow 50 expands upon exit from the turbine combustor 32 and upon entrance into the turbine 34, thereby causing the turbine 34 to rotate.
  • The rotation of the turbine 34 may cause the turbine shaft 22 and also the turbine compressor 30 to rotate. The turbine shaft 22 may rotate in a turbine generator 20, such that rotation of the turbine shaft 22 may cause the turbine generator 20 to generate electricity. In embodiments, the turbine compressor 30 may be fluidly connected to the turbine combustor 32 such that the turbine compressor 30 may compress and deliver the recirculated low oxygen content gas flow 50 to the turbine combustor 32.
  • At least a second portion of the recirculated low oxygen content gas flow 50 from the output of the turbine compressor 30 may be extracted through an extraction conduit 48 which may be regulated by an extraction valve 45. In some embodiments, the extraction valve 45 may be fluidly connected to a bypass conduit 49 at a point that is either upstream of or downstream of a turbine bypass valve 47. In some embodiments, the extraction conduit 48 may be fluidly connected to a gas separation system such as a carbon capture sequestration (CCS) system. In still other embodiments, the gas separation system may produce a stream of concentrated carbon dioxide and concentrated nitrogen, both with a low oxygen content. In some embodiments, the extraction valve 45 may be adjusted to maintain a constant mass balance in the power plant arrangement 10. As used herein, the term "constant mass balance" means that the system inputs, including fuel and air, are balanced with the system outputs via extraction, including carbon dioxide, nitrogen, and water.
  • The compressed ambient gas flow rate and the fuel stream flow rate may be adjusted to achieve substantially stoichiometric combustion. As used herein, the term "substantially stoichiometric combustion" means that the combustion reaction involves substantially stoichiometric burning of fuel and oxygen in the combustion system. In other terms, the oxygen content after the combustion reaction may be below about 5 vol%, below about 2 vol%, or below about 1 vol%. In some embodiments, the compressed ambient gas flow rate and/or the fuel stream flow rate may be adjusted based on measurements of oxygen and/or carbon dioxide present in the exhaust of the turbine 34 and/or in the recirculated low oxygen content gas flow 50.
  • In some embodiments, the main air compressor 12 may further comprise adjustable inlet guide vanes to control the flow of air into the main air compressor 12. The inlet guide vanes of the main air compressor may be used to regulate the compressed ambient gas flow rate that is delivered to the turbine combustor 32. In some embodiments, the turbine compressor 30 may further comprise adjustable inlet guide vanes to control the flow of air into the turbine compressor 30.
  • As illustrated in FIG. 1, in some embodiments, the turbine shaft 22 may be a "cold-end drive" configuration, meaning the turbine shaft 22 may connect to the turbine generator 20 at the compressor end of the turbine assembly. In other embodiments, the turbine shaft 22 may be a "hot-end drive" configuration, meaning the turbine shaft 22 may connect to the turbine generator 20 at the turbine end of the turbine assembly.
  • As used herein, the term "recirculated low oxygen content gas flow" refers to the gas flow generated by the burning of the combustible mixture in the turbine combustor 32 and flowing through a recirculation loop 52. In some embodiments, the term "low oxygen content" refers to an oxygen content of below about 5 vol%, below about 2 vol%, or below about 1 vol%. The concentration of oxygen present in the recirculated low oxygen content gas flow 50 may be detected, upon exit from the turbine compressor 30 using a first oxygen sensor or upon exit from the turbine 34 using a second oxygen sensor or both.
  • In some embodiments, the recirculated low oxygen content gas flow 50 may be directed from the turbine 34 through the recirculation loop 52 to a heat recovery steam generator 36 for the generation of steam. A steam turbine may be configured to generate additional electricity using the steam from the heat recovery steam generator 36, and the steam turbine may be connected to a steam generator. In some embodiments, the steam turbine may be arranged to be connected to the turbine shaft 22. The recirculated low oxygen content gas flow 50 may then be directed back into the recirculation loop 52 to a recirculated gas flow cooler 40. In still other embodiments, the recirculation loop 52 may not contain a heat recovery steam generator 36 and the recirculated low oxygen content gas flow 50 may instead be introduced directly into the recirculated gas flow cooler 40 upon exit from the turbine 34. In other embodiments, the recirculation loop 52 may not comprise the recirculated gas flow cooler 40.
  • The recirculated gas flow cooler 40 may be incorporated into the recirculation loop 52 anywhere downstream from the turbine 34. The recirculated gas flow cooler 40 may be configured to lower the temperature of the recirculated low oxygen content gas flow 50 to a suitable temperature for downstream delivery into the turbine compressor 30 via the recirculation loop 52. In some embodiments, a suitable temperature may be below about 66 °C, below about 49 °C, or below about 45 °C.
  • In some embodiments, at least a third portion of the recirculated low oxygen content gas flow 50 may be delivered from the turbine compressor 30 to the turbine 34 as a secondary flow. The gas turbine assembly ,may further comprise a secondary flow path 31 that delivers at least a second portion of the recirculated low oxygen content gas flow 50 from the turbine compressor 30 to the turbine 34 as a secondary flow. The secondary flow may be used to cool and seal the turbine 34, including individual components of the turbine 34 such as the turbine shroud, the turbine nozzle, the turbine blade tip, the turbine bearing support housing, and the like. After cooling and sealing the turbine 34 and any individual turbine components, the secondary flow may be directed into the recirculation loop 52 near the output of the turbine 34.
  • In some embodiments, the turbine combustor 32 may be bypassed with at least a portion of the recirculated low oxygen content gas flow 50 using a bypass conduit 49. The bypass conduit 49 may be located downstream of the turbine compressor 30 and may be in fluid connection with a portion of the recirculated gas flow 50 from the output of the turbine compressor 30. In some embodiments, a bypass flow through the bypass conduit 49 may be regulated by a turbine bypass valve 47. The turbine bypass valve 47 may be used to adjust a bypass flow rate through the bypass conduit 49. In some embodiments, the bypass flow may be fluidly connected to the recirculation loop 52 downstream of the turbine 34.
  • In some embodiments, the at least a first portion of the compressed ambient gas flow 26 may be further compressed prior to delivery into the turbine combustor 32. The at least a first portion of the compressed ambient gas flow 26 may be further compressed by a booster compressor 24. The booster compressor 24 may be incorporated downstream from and in fluid connection with the main air compressor 12 and upstream of an in fluid connection with the turbine combustor 32. In some embodiments, the compressed ambient gas flow rate may be varied by adjusting the speed of the booster compressor 24 and/or by adjusting the inlet guide vanes of the booster compressor 24.
  • In some embodiments, a blower 42 may be used to increase the pressure of the recirculated low oxygen content gas flow 50. The blower 42 may be fluidly connected to the recirculation loop 52 upstream of or downstream from the recirculated gas flow cooler 40. The blower 42 may be configured to increase the pressure of the recirculated low oxygen content gas flow 50 prior to delivery into the turbine compressor 30 via the recirculation loop 52.
  • In some embodiments, an excess portion, if any, of the recirculated low oxygen content gas flow 50 may be vented from the gas turbine assembly. The power plant arrangement 10 may include a damper door 38 connected to the recirculation loop 52. The damper door 38 may be opened to vent a portion of the recirculated low oxygen gas content flow 50 to the atmosphere.
  • Control Method for a Master Train and a Slave Train
  • As used herein, the term "master train" refers to any gas turbine assembly that also includes a main air compressor. As used herein, the term "slave train" refers to any gas turbine assembly that does not also include a main air compressor. Thus, any given slave train requires at least one master train for operation.
  • In an embodiment, a method for controlling at least one master train of a stoichiometric exhaust gas recirculation power plant arrangement 100 is provided, wherein ambient air is compressed using a main air compressor 12 to form at least a first portion of a compressed ambient gas flow 26. In some embodiments, an air supply valve 15 that fluidly connects the main air compressor 12 to an inter-train conduit 19 may be opened. In some embodiments, a master air injection valve 25 that fluidly connects the inter-train conduit 19 to a master turbine combustor 32 may be opened. An excess portion, if any, of the at least a first portion of the compressed ambient gas flow 26 may be vented to the atmosphere via a master variable bleed valve 14.
  • At least a first portion of the compressed ambient gas flow 26, having a master compressed ambient gas flow rate, may be delivered to a master turbine combustor 32 that is fluidly connected to the main air compressor 12. A master fuel stream 28, having a master fuel stream flow rate, may also be delivered to the master turbine combustor 32. The at least a first portion of the compressed ambient gas flow 26 may then be mixed with at least a first portion of a master recirculated low oxygen content gas flow 50 and the master fuel stream 28 to form a master combustible mixture. The master combustible mixture may be burned in the master turbine combustor 32 to produce the master recirculated low oxygen content gas flow 50. In some embodiments, the master fuel stream flow rate may be controlled by a master gas control valve 27.
  • A master turbine 34 may be driven using the master recirculated low oxygen content gas flow 50, thereby causing the master turbine 34 to rotate. As used herein, the term "driven using the master recirculated low oxygen content gas flow" means the master recirculated low oxygen content gas flow 50 expands upon exit from the master turbine combustor 32 and upon entrance into the master turbine 34, thereby causing the master turbine 34 to rotate.
  • The rotation of the master turbine 34 may cause the master turbine shaft 22 and also the master turbine compressor 30 to rotate. The master turbine shaft 22 may rotate in a master turbine generator 20, such that rotation of the master turbine shaft 22 may cause the master turbine generator 20 to generate electricity. In embodiments, the master turbine compressor 30 may be fluidly connected to the master turbine combustor 32 such that the master turbine compressor 30 may compress and deliver the master recirculated low oxygen content gas flow 50 to the master turbine combustor 32.
  • At least a second portion of the master recirculated gas flow 50 from the output of the master turbine compressor 30 may be extracted through a master extraction conduit 48 which may be regulated by a master extraction valve 45. In some embodiments, the master extraction valve 45 may be fluidly connected to a master bypass conduit 49 at a point that is either upstream of or downstream of a master turbine bypass valve 47. In some embodiments, the master extraction conduit 48 may be fluidly connected to a master gas separation system such as a master carbon capture sequestration (CCS) system. In still other embodiments, the master gas separation system may produce a stream of concentrated carbon dioxide and concentrated nitrogen, both with a low oxygen content. In some embodiments, the master extraction valve 45 may be adjusted to maintain a constant mass balance in the master train of the power plant arrangement 100. As used herein, the term "constant mass balance" means that the system inputs, including fuel and air, are balanced with the system outputs via extraction, including carbon dioxide, nitrogen, and water.
  • The master compressed ambient gas flow rate and the master fuel stream flow rate may be adjusted to achieve substantially stoichiometric combustion. As used herein, the term "substantially stoichiometric combustion" means that the combustion reaction involves substantially stoichiometric burning of fuel and oxygen in the combustion system. In other terms, the oxygen content after the combustion reaction may be below about 5 vol%, below about 2 vol%, or below about 1 vol%. In some embodiments, the master compressed ambient gas flow rate and/or the master fuel stream flow rate may be adjusted based on measurements of oxygen and/or carbon dioxide present in the exhaust of the master turbine 34 and/or in the master recirculated low oxygen content gas flow 50.
  • The main air compressor 12 may further comprise adjustable inlet guide vanes to control the flow of air into the main air compressor 12. The inlet guide vanes of the main air compressor may be used to regulate the compressed ambient gas flow rate that is delivered to the turbine combustor 32. Additionally, the master turbine compressor 30 may further comprise adjustable inlet guide vanes to control the flow of air into the master turbine compressor 30.
  • As illustrated in FIG. 2, in some embodiments, the master turbine shaft 22 may be a "cold-end drive" configuration, meaning the master turbine shaft 22 may connect to the master turbine generator 20 at the compressor end of the turbine assembly. In other embodiments, the master turbine shaft 22 may be a "hot-end drive" configuration, meaning the master turbine shaft 22 may connect to the master turbine generator 20 at the master turbine end of the turbine assembly.
  • As used herein, the term "master recirculated low oxygen content gas flow" refers to the gas flow generated by the burning of the master combustible mixture in the master turbine combustor 32 and flowing through a master recirculation loop 52. In some embodiments, the term "low oxygen content" refers to an oxygen content of below about 5 vol%, below about 2 vol%, or below about 1 vol%. The concentration of oxygen present in the master recirculated low oxygen content gas flow 50 may be detected, upon exit from the master turbine compressor 30 using a first master oxygen sensor or upon exit from the master turbine 34 using a second master oxygen sensor or both.
  • In some embodiments, the master recirculated low oxygen content gas flow 50 may be directed from the master turbine 34 through the master recirculation loop 52 to a master heat recovery steam generator 36 for the generation of steam. A master steam turbine may be configured to generate additional electricity using the steam from the master heat recovery steam generator 36, and the master steam turbine may be connected to a master steam generator. In some embodiments, the master steam turbine may be arranged to be connected to the master turbine shaft 22. The master recirculated low oxygen content gas flow 50 may then be directed back into the master recirculation loop 52 to a master recirculated gas flow cooler 40. In still other embodiments, the master recirculation loop 52 may not contain a master heat recovery steam generator 36 and the master recirculated low oxygen content gas flow 50 may instead be introduced directly into the master recirculated gas flow cooler 40 upon exit from the master turbine 34. In other embodiments, the master recirculation loop 52 may not comprise the master recirculated gas flow cooler 40.
  • The master recirculated gas flow cooler 40 may be incorporated into the master recirculation loop 52 anywhere downstream from the master turbine 34. The master recirculated gas flow cooler 40 may be configured to lower the temperature of the master recirculated low oxygen content gas flow 50 to a suitable temperature for downstream delivery into the master turbine compressor 30 via the master recirculation loop 52. In some embodiments, a suitable temperature may be below about 66 °C, below about 49 °C, or below about 45 °C.
  • In some embodiments, at least a third portion of the master recirculated low oxygen content gas flow 50 may be delivered from the master turbine compressor 30 to the master turbine 34 as a master secondary flow. The gas turbine assembly may further comprise a master secondary flow path 31 that delivers at least a third portion of the master recirculated low oxygen content gas flow 50 from the master turbine compressor 30 to the master turbine 34 as a master secondary flow. The master secondary flow may be used to cool and seal the master turbine 34, including individual components of the master turbine 34 such as the turbine shroud, the turbine nozzle, the turbine blade tip, the turbine bearing support housing, and the like. After cooling and sealing the master turbine 34 and any individual turbine components, the master secondary flow may be directed into the master recirculation loop 52 near the output of the master turbine 34.
  • In some embodiments, the master turbine combustor 32 may be bypassed with at least a portion of the master recirculated low oxygen content gas flow 50 using a master bypass conduit 49. The master bypass conduit 49 may be located downstream of the master turbine compressor 30 and may be in fluid connection with a portion of the master recirculated gas flow 50 from the output of the master turbine compressor 30. In some embodiments, a master bypass flow through the master bypass conduit 49 may be regulated by a master turbine bypass valve 47. The master turbine bypass valve 47 may be used to adjust a master bypass flow rate through the master bypass conduit 49. In some embodiments, the master bypass flow may be fluidly connected to the master recirculation loop 52 downstream of the master turbine 34.
  • In some embodiments, the at least a first portion of the compressed ambient gas flow 26 may be further compressed prior to delivery into the master turbine combustor 32. The at least a first portion of the compressed ambient gas flow 26 may be further compressed by a master booster compressor 24. The master booster compressor 24 may be incorporated downstream from and in fluid connection with the main air compressor 12 and upstream of an in fluid connection with the master turbine combustor 32. In some embodiments, the master compressed ambient gas flow rate may be varied by adjusting the speed of the master booster compressor 24 and/or by adjusting the inlet guide vanes of the master booster compressor 24.
  • In some embodiments, a master blower 42 may be used to increase the pressure of the master recirculated low oxygen content gas flow 50. The master blower 42 may be fluidly connected to the master recirculation loop 52 upstream of or downstream of the master recirculated gas flow cooler 40. The master blower 42 may be configured to increase the pressure of the master recirculated low oxygen content gas flow 50 prior to delivery into the master turbine compressor 30 via the master recirculation loop 52.
  • In some embodiments, an excess portion, if any, of the master recirculated low oxygen content gas flow 50 may be vented from the master train. The master train may include a master damper door 38 connected to the master recirculation loop 52. The master damper door 38 may be opened to vent a portion of the master recirculated low oxygen gas content flow 50 to the atmosphere.
  • In an embodiment, a method for controlling at least one slave train of a stoichiometric exhaust gas recirculation power plant arrangement 100 is provided. An inter-train valve 16 may be opened, fluidly connecting the slave train to the master train. Additionally, a slave air injection valve 65 may be opened to fluidly connect the inter-train conduit 19 to the slave turbine combustor 72. At least a second portion of the compressed ambient gas flow 66 may be delivered directly to a slave turbine combustor 72. An excess portion, if any, of the at least a second portion of the compressed ambient gas flow 66 may be vented to the atmosphere via a slave variable bleed valve 18.
  • At least a second portion of the compressed ambient gas flow 66, having a slave compressed ambient gas flow rate, may be delivered to a slave turbine combustor 72 that is fluidly connected to the main air compressor 12. A slave fuel stream 68, having a slave fuel stream flow rate, may also be delivered to the slave turbine combustor 72. The at least a second portion of the compressed ambient gas flow 66 may then be mixed with at least a first portion of a slave recirculated low oxygen content gas flow 90 and the slave fuel stream 68 to form a slave combustible mixture. The slave combustible mixture may be burned in the slave turbine combustor 72 to produce the slave recirculated low oxygen content gas flow 90. In some embodiments, the slave fuel stream flow rate may be controlled by a slave gas control valve 67.
  • A slave turbine 74 may be driven using the slave recirculated low oxygen content gas flow 90, thereby causing the slave turbine 74 to rotate. As used herein, the term "driven using the slave recirculated low oxygen content gas flow" means the slave recirculated low oxygen content gas flow 90 expands upon exit from the slave turbine combustor 72 and upon entrance into the slave turbine 74, thereby causing the slave turbine 74 to rotate.
  • The rotation of the slave turbine 74 may cause the slave turbine shaft 62 and also the slave turbine compressor 70 to rotate. The slave turbine shaft 62 may rotate in a slave turbine generator 60, such that rotation of the slave turbine shaft 62 may cause the slave turbine generator 60 to generate electricity. In embodiments, the slave turbine compressor 70 may be fluidly connected to the slave turbine combustor 72 such that the slave turbine compressor 70 may compress and deliver the slave recirculated low oxygen content gas flow 90 to the slave turbine combustor 72.
  • At least a second portion of the slave recirculated gas flow 90 from the output of the slave turbine compressor 70 may be extracted through a slave extraction conduit 88 which may be regulated by a slave extraction valve 85. In some embodiments, the slave extraction valve 85 may be fluidly connected to a slave bypass conduit 89 at a point that is either upstream of or downstream of a slave turbine bypass valve 87. In some embodiments, the slave extraction conduit 88 may be fluidly connected to a slave gas separation system such as a slave carbon capture sequestration (CCS) system. In still other embodiments, the slave gas separation system may produce a stream of concentrated carbon dioxide and concentrated nitrogen, both with a low oxygen content. In some embodiments, the slave extraction valve 85 may be adjusted to maintain a constant mass balance in the slave train of the power plant arrangement 100. As used herein, the term "constant mass balance" means that the system inputs, including fuel and air, are balanced with the system outputs via extraction, including carbon dioxide, nitrogen, and water.
  • The slave compressed ambient gas flow rate and the slave fuel stream flow rate may be adjusted to achieve substantially stoichiometric combustion. As used herein, the term "substantially stoichiometric combustion" means that the combustion reaction involves substantially stoichiometric burning of fuel and oxygen in the combustion system. In other terms, the oxygen content after the combustion reaction may be below about 5 vol%, below about 2 vol%, or below about 1 vol%. In some embodiments, the slave compressed ambient gas flow rate and/or the slave fuel stream flow rate may be adjusted based on measurements of oxygen and/or carbon dioxide present in the exhaust of the slave turbine 74 and/or in the slave recirculated low oxygen content gas flow 90.
  • The slave turbine compressor 70 may further comprise adjustable inlet guide vanes to control the flow of air into the slave turbine compressor 70.
  • As illustrated in FIG. 2, in some embodiments, the slave turbine shaft 62 may be a "cold-end drive" configuration, meaning the slave turbine shaft 62 may connect to the slave turbine generator 60 at the compressor end of the slave train. In other embodiments, the slave turbine shaft 62 may be a "hot-end drive" configuration, meaning the slave turbine shaft 62 may connect to the slave turbine generator 60 at the slave turbine end of the slave train.
  • As used herein, the term "slave recirculated low oxygen content gas flow" refers to the gas flow generated by the burning of the slave combustible mixture in the slave turbine combustor 72 and flowing through a slave recirculation loop 92. In some embodiments, the term "low oxygen content" refers to an oxygen content of below about 5 vol%, below about 2 vol%, or below about 1 vol%. The concentration of oxygen present in the slave recirculated low oxygen content gas flow 90 may be detected, upon exit from the slave turbine compressor 70 using a first slave oxygen sensor or upon exit from the slave turbine 74 using a second slave oxygen sensor or both.
  • In some embodiments, the slave recirculated low oxygen content gas flow 90 may be directed from the slave turbine 74 through the slave recirculation loop 92 to a slave heat recovery steam generator 76 for the generation of steam. A slave steam turbine may be configured to generate additional electricity using the steam from the slave heat recovery steam generator 76, and the slave steam turbine may be connected to a slave steam generator. In some embodiments, the slave steam turbine may be arranged to be connected to the slave turbine shaft 62. The slave recirculated low oxygen content gas flow 90 may then be directed back into the slave recirculation loop 92 to a slave recirculated gas flow cooler 80. In still other embodiments, the slave recirculation loop 92 may not contain a slave heat recovery steam generator 76 and the slave recirculated low oxygen content gas flow 90 may instead be introduced directly into the slave recirculated gas flow cooler 80 upon exit from the slave turbine 74. In other embodiments, the slave recirculation loop 92 may not comprise the slave recirculated gas flow cooler 80.
  • The slave recirculated gas flow cooler 80 may be incorporated into the slave recirculation loop 92 anywhere downstream from the slave turbine 74. The slave recirculated gas flow cooler 80 may be configured to lower the temperature of the slave recirculated low oxygen content gas flow 90 to a suitable temperature for downstream delivery into the slave turbine compressor 70 via the slave recirculation loop 92. In some embodiments, a suitable temperature may be below about 66 °C, below about 49 °C, or below about 45 °C.
  • In some embodiments, at least a third portion of the slave recirculated low oxygen content gas flow 90 may be delivered from the slave turbine compressor 70 to the slave turbine 74 as a slave secondary flow. The slave train may further comprise a slave secondary flow path 71 that delivers at least a third portion of the slave recirculated low oxygen content gas flow 90 from the slave turbine compressor 70 to the slave turbine 74 as a slave secondary flow. The slave secondary flow may be used to cool and seal the slave turbine 74, including individual components of the slave turbine 74 such as the turbine shroud, the turbine nozzle, the turbine blade tip, the turbine bearing support housing, and the like. After cooling and sealing the slave turbine 74 and any individual turbine components, the slave secondary flow may be directed into the slave recirculation loop 92 near the output of the slave turbine 74.
  • In some embodiments, the slave turbine combustor 72 may be bypassed with at least a portion of the slave recirculated low oxygen content gas flow 90 using a slave bypass conduit 89. The slave bypass conduit 89 may be located downstream of the slave turbine compressor 70 and may be in fluid connection with a portion of the slave recirculated gas flow 90 from the output of the slave turbine compressor 70. In some embodiments, a slave bypass flow through the slave bypass conduit 89 may be regulated by a slave turbine bypass valve 87. The slave turbine bypass valve 87 may be used to adjust a slave bypass flow rate through the slave bypass conduit 89. In some embodiments, the slave bypass flow may be fluidly connected to the slave recirculation loop 92 downstream of the slave turbine 74.
  • In some embodiments, the at least a second portion of the compressed ambient gas flow 66 may be further compressed prior to delivery into the slave turbine combustor 72. The at least a second portion of the compressed ambient gas flow 66 may be further compressed by a slave booster compressor 64. The slave booster compressor 64 may be incorporated downstream from and in fluid connection with the main air compressor 12 and upstream of an in fluid connection with the slave turbine combustor 72. In some embodiments, the slave compressed ambient gas flow rate may be varied by adjusting the speed of the slave booster compressor 64 and/or the inlet guide vanes of the slave booster compressor 64.
  • In some embodiments, a slave blower 82 may be used to increase the pressure of the slave recirculated low oxygen content gas flow 90. The slave blower 82 may be fluidly connected to the slave recirculation loop 92 upstream of or downstream from the slave recirculated gas flow cooler 80. The slave blower 82 may be configured to increase the pressure of the slave recirculated low oxygen content gas flow 90 prior to delivery into the slave turbine compressor 70 via the slave recirculation loop 92.
  • In some embodiments, an excess portion, if any, of the slave recirculated low oxygen content gas flow 90 may be vented from the slave train. The slave train may include a slave damper door 78 connected to the slave recirculation loop 92. The slave damper door 78 may be opened to vent a portion of the slave recirculated low oxygen gas content flow 90 to the atmosphere.
  • Other configurations and methods of operation are provided by U.S. Patent Applications including "Power Plant and Method of Operation" to Daniel Snook, Lisa Wichmann, Sam Draper, Noemie Dion Ouellet, and Scott Rittenhouse (filed August 25, 2011), "Power Plant and Method of Operation" to Daniel Snook, Lisa Wichmann, Sam Draper, Noemie Dion Ouellet, and Scott Rittenhouse (filed August 25, 2011), "Power Plant Start-Up Method" to Daniel Snook, Lisa Wichmann, Sam Draper, Noemie Dion Ouellet, and Scott Rittenhouse (filed August 25, 2011), "Power Plant and Method of Use" to Daniel Snook, Lisa Wichmann, Sam Draper, and Noemie Dion Ouellet (filed August 25, 2011), "Power Plant and Method of Operation" to Predrag Popovic (filed August 25, 2011), "Power Plant and Method of Operation" to Sam Draper and Kenneth Kohl (filed August 25, 2011), "Power Plant and Method of Operation" to Sam Draper (filed August 25, 2011), "Power Plant and Method of Operation" to Sam Draper (filed August 25, 2011), "Power Plant and Method of Operation" to Lisa Wichmann (filed August 25, 2011), and "Power Plant and Control Method" to Karl Dean Minto (filed August 25, 2011), the disclosures of which are incorporated in full by reference herein.
  • Various aspects and embodiments of the present invention are defined by the following numbered clauses:
    1. 1. A method for controlling a stoichiometric exhaust gas recirculation power plant arrangement, comprising the steps of:
      • compressing ambient air into a compressed ambient gas flow with at least one main air compressor;
      • delivering at least a first portion of the compressed ambient gas flow, with a compressed ambient gas flow rate, to a turbine combustor that is fluidly connected to the at least one main air compressor;
      • delivering a fuel stream, having a fuel stream flow rate, to the turbine combustor for mixing with the at least a first portion of the compressed ambient gas flow and with at least a first portion of a recirculated low oxygen content gas flow to form a combustible mixture;
      • burning the combustible mixture in the turbine combustor and thereby forming the recirculated low oxygen content gas flow and driving a turbine connected to a turbine compressor via a turbine shaft;
      • recirculating the at least a first portion of the recirculated low oxygen content gas flow from the turbine to the turbine compressor using a recirculation loop;
      • adjusting the compressed ambient gas flow rate and adjusting the fuel stream flow rate to achieve substantially stoichiometric combustion;
      • venting an excess portion, if any, of the at least a first portion of the compressed ambient gas flow; and
      • extracting at least a second portion of the recirculated low oxygen content gas flow using an extraction conduit that is fluidly connected to the turbine compressor.
    2. 2. The method of clause 1, further comprising delivering a secondary flow through a secondary flow path, wherein the secondary flow path delivers at least a third portion of the recirculated low oxygen content gas flow from the turbine compressor to the turbine for cooling and sealing the turbine and thereafter into the recirculation loop.
    3. 3. The method of clause 1, wherein the step of adjusting the compressed ambient gas flow rate comprises adjusting a plurality of inlet guide vanes of the at least one main air compressor.
    4. 4. The method of clause 1, further comprising delivering the at least a first portion of the compressed ambient gas flow to a booster compressor, wherein the booster compressor is configured to compress and to deliver the at least a first portion of the compressed ambient gas to flow to the turbine combustor.
    5. 5. The method of clause 4, wherein the step of adjusting the compressed ambient gas flow rate comprises adjusting a speed or a plurality of inlet guide vanes of the booster compressor.
    6. 6. The method of clause 1, wherein the step of adjusting the fuel stream flow rate comprises adjusting one or more gas control valves.
    7. 7. The method of clause 1, wherein the step of adjusting the compressed ambient gas flow rate comprises adjusting a variable bleed valve, in fluid communication with the at least one main air compressor, to vent a portion of the at least a first portion of the compressed ambient gas flow to
    8. 8. The method of clause 1, wherein the step of extracting comprises adjusting an extraction valve in fluid communication with the extraction conduit to keep the mass balance of the power plant arrangement constant.
    9. 9. A method for controlling at least one master train of a stoichiometric exhaust gas recirculation power plant arrangement, comprising the steps of:
      • compressing ambient air into a compressed ambient gas flow with at least one main air compressor;
      • delivering at least a first portion of the compressed ambient gas flow, with a master compressed ambient gas flow rate, to a master turbine combustor that is fluidly connected to the at least one main air compressor;
      • delivering a master fuel stream, having a master fuel stream flow rate, to the master turbine combustor for mixing with the at least a first portion of the compressed ambient gas flow and with at least a first portion of a master recirculated low oxygen content gas flow to form a master combustible mixture;
      • burning the master combustible mixture in the master turbine combustor and thereby forming the master recirculated low oxygen content gas flow and driving a master turbine connected to a master turbine compressor via a master turbine shaft;
      • recirculating the at least a first portion of the master recirculated low oxygen content gas flow from the master turbine to the master turbine compressor using a master recirculation loop;
      • adjusting the master compressed ambient gas flow rate and adjusting the master fuel stream flow rate to achieve substantially stoichiometric combustion;
      • venting an excess portion, if any, of the at least a first portion of the compressed ambient gas flow; and
      • extracting at least a second portion of the master recirculated low oxygen content gas flow using a master extraction conduit that is fluidly connected to the master turbine compressor.
    10. 10. The method of clause 9, further comprising delivering a master secondary flow through a master secondary flow path, wherein the master secondary flow path delivers at least a third portion of the master recirculated low oxygen content gas flow from the master turbine compressor to the master turbine for cooling and sealing the master turbine and thereafter into the master recirculation loop.
    11. 11. The method of clause 9, wherein the step of adjusting the compressed ambient gas flow rate comprises adjusting a plurality of inlet guide vanes of the at least one main air compressor.
    12. 12. The method of clause 9, further comprising delivering the at least a first portion of the compressed ambient gas flow to a master booster compressor, wherein the master booster compressor is configured to compress and to deliver the at least a first portion of the compressed ambient gas to flow to the master turbine combustor.
    13. 13. The method of clause 9, wherein the step of adjusting the master fuel stream flow rate comprises adjusting one or more master gas control valves.
    14. 14. The method of clause 9, wherein the step of adjusting the compressed ambient gas flow rate comprises adjusting a master variable bleed valve, in fluid communication with the at least one main air compressor, to vent a portion of the at least a first portion of the compressed ambient gas flow to the atmosphere.
    15. 15. The method of clause 9, wherein the step of extracting comprises adjusting a master extraction valve in fluid communication with the master extraction conduit to keep the mass balance of the master train constant.
    16. 16. The method of clause 9, further comprising controlling at least one slave train of a stoichiometric exhaust gas recirculation power plant arrangement, comprising the steps of:
      • opening a slave air injection valve that fluidly connects the inter-train conduit to a slave turbine combustor;
      • delivering at least a second portion of the compressed ambient gas flow, with a slave compressed ambient gas flow rate, to a slave turbine combustor that is fluidly connected to the at least one main air compressor;
      • delivering a slave fuel stream, having a slave fuel stream flow rate, to the slave turbine combustor for mixing with the at least a second portion of the compressed ambient gas flow and with at least a first portion of a slave recirculated low oxygen content gas flow to form a slave combustible mixture;
      • burning the slave combustible mixture in the slave turbine combustor and thereby forming the slave recirculated low oxygen content gas flow and driving a slave turbine connected to a slave turbine compressor via a slave turbine shaft;
      • recirculating the at least a first portion of the slave recirculated low oxygen content gas flow from the slave turbine to the slave turbine compressor using a slave recirculation loop;
      • adjusting the slave compressed ambient gas flow rate and adjusting the slave fuel stream flow rate to achieve substantially stoichiometric combustion;
      • venting an excess portion, if any, of the at least a second portion of the compressed ambient gas flow; and
      • extracting at least a second portion of the slave recirculated low oxygen content gas flow using a slave extraction conduit that is fluidly connected to the slave turbine compressor.
    17. 17. The method of clause 16, further comprising delivering a slave secondary flow through a slave secondary flow path, wherein the slave secondary flow path delivers at least a third portion of the slave recirculated low oxygen content gas flow from the slave turbine compressor to the slave turbine for cooling and sealing the slave turbine and thereafter into the slave recirculation loop.
    18. 18. The method of clause 16, wherein the step of adjusting the slave fuel stream flow rate comprises adjusting one or more slave gas control valves.
    19. 19. The method of clause 16, wherein the step of adjusting the slave compressed ambient gas flow rate comprises adjusting a slave variable bleed valve, in fluid communication with the at least one main air compressor, to vent a portion of the at least a second portion of the compressed ambient gas flow to the atmosphere.
    20. 20. The method of clause 16, wherein the step of extracting comprises adjusting a slave extraction valve in fluid communication with the slave extraction conduit to keep the mass balance of the slave train constant.

Claims (13)

  1. A method for controlling at least one master train of a stoichiometric exhaust gas recirculation power plant arrangement, comprising the steps of:
    compressing ambient air into a compressed ambient gas flow with at least one main air compressor (12);
    opening a master air injection valve (25) that fluidly connects an inter-train conduit (19) to a master turbine combustor (32);
    delivering at least a first portion of the compressed ambient gas flow (26), with a master compressed ambient gas flow rate, to a master turbine combustor (32) that is fluidly connected to the at least one main air compressor (12);
    delivering a master fuel stream (28), having a master fuel stream flow rate, to the master turbine combustor (32) for mixing with the at least a first portion of the compressed ambient gas flow (26) and with at least a first portion of a master recirculated low oxygen content gas flow (50) to form a master combustible mixture;
    burning the master combustible mixture in the master turbine combustor (32) and thereby forming the master recirculated low oxygen content gas flow (50) and driving a master turbine (34) connected to a master turbine compressor (30) via a master turbine shaft (22);
    recirculating the at least a first portion of the master recirculated low oxygen content gas flow (50) from the master turbine (34) to the master turbine compressor (30) using a master recirculation loop (52);
    adjusting the master compressed ambient gas flow rate and adjusting the master fuel stream flow rate to achieve substantially stoichiometric combustion;
    venting an excess portion, if any, of the at least a first portion of the compressed ambient gas flow (26); and
    extracting at least a second portion of the master recirculated low oxygen content gas flow (50) using a master extraction conduit (48) that is fluidly connected the master turbine compressor (30).
  2. The method of claim 1, further comprising delivering a master secondary flow through a master secondary flow path (31), wherein the master secondary flow path (31) delivers at least a third portion of the master recirculated low oxygen content gas flow (50) from the master turbine compressor (30) to the master turbine (34) for cooling and sealing the master turbine (34) and thereafter into the master recirculation loop (52).
  3. The method of claim 1 or claim 2, wherein the step of adjusting the compressed ambient gas flow rate comprises adjusting a plurality of inlet guide vanes of the at least one main air compressor (12).
  4. The method of any preceding claim, wherein the step of adjusting the master fuel stream flow rate comprises adjusting one or more master gas control valves (27).
  5. The method of any preceding claim, wherein the step of extracting comprises adjusting a master extraction valve (45) in fluid communication with the master extraction conduit (48) to keep the mass balance of the master train constant.
  6. The method of any preceding claim, further comprising controlling at least one slave train of a stoichiometric exhaust gas recirculation power plant arrangement, comprising the steps of:
    opening a slave air injection valve (65) that fluidly connects the inter-train conduit (19) to a slave turbine combustor (72);
    delivering at least a second portion of the compressed ambient gas flow (66), with a slave compressed ambient gas flow rate, to a slave turbine combustor (72) that is fluidly connected to the at least one main air compressor (12);
    delivering a slave fuel stream (68), having a slave fuel stream flow rate, to the slave turbine combustor (72) for mixing with the at least a second portion of the compressed ambient gas flow (66) and with at least a first portion of a slave recirculated low oxygen content gas flow (90) to form a slave combustible mixture;
    burning the slave combustible mixture in the slave turbine combustor (72) and thereby forming the slave recirculated low oxygen content gas flow (90) and driving a slave turbine (74) connected to a slave turbine compressor (70) via a slave turbine shaft (62);
    recirculating the at least a first portion of the slave recirculated low oxygen content gas flow (90) from the slave turbine (74) to the slave turbine compressor (70) using a slave recirculation loop (92);
    adjusting the slave compressed ambient gas flow rate and adjusting the slave fuel stream flow rate to achieve substantially stoichiometric combustion;
    venting an excess portion, if any, of the at least a second portion of the compressed ambient gas flow (66); and
    extracting at least a second portion of the slave recirculated low oxygen content gas flow (90) using a slave extraction conduit (88) that is fluidly connected to the slave turbine compressor (70).
  7. The method of claim 6, further comprising delivering a slave secondary flow through a slave secondary flow path (71), wherein the slave secondary flow path (71) delivers at least a third portion of the slave recirculated low oxygen content gas flow (90) from the slave turbine compressor (70) to the slave turbine (74) for cooling and sealing the slave turbine (74) and thereafter into the slave recirculation loop (92).
  8. The method of claim 6 or claim 7, wherein the step of adjusting the slave fuel stream flow rate comprises adjusting one or more slave gas control valves (67).
  9. The method of any one of claims 6 to 8, wherein the step of adjusting the slave compressed ambient gas flow rate comprises adjusting a slave variable bleed valve (18), in fluid communication with the at least one main air compressor (12), to vent a portion of the at least a second portion of the compressed ambient gas flow (66) to the atmosphere.
  10. The method of any one of claims 6 to 9, wherein the step of extracting comprises adjusting a slave extraction valve (85) in fluid communication with the slave extraction conduit (88) to keep the mass balance of the slave train constant.
  11. A method for controlling a stoichiometric exhaust gas recirculation power plant arrangement, comprising the steps of:
    compressing ambient air into a compressed ambient gas flow with at least one main air compressor;
    delivering at least a first portion of the compressed ambient gas flow, with a compressed ambient gas flow rate, to a turbine combustor that is fluidly connected to the at least one main air compressor;
    delivering a fuel stream, having a fuel stream flow rate, to the turbine combustor for mixing with the at least a first portion of the compressed ambient gas flow and with at least a first portion of a recirculated low oxygen content gas flow to form a combustible mixture;
    burning the combustible mixture in the turbine combustor and thereby forming the recirculated low oxygen content gas flow and driving a turbine connected to a turbine compressor via a turbine shaft;
    recirculating the at least a first portion of the recirculated low oxygen content gas flow from the turbine to the turbine compressor using a recirculation loop;
    adjusting the compressed ambient gas flow rate and adjusting the fuel stream flow rate to achieve substantially stoichiometric combustion;
    venting an excess portion, if any, of the at least a first portion of the compressed ambient gas flow; and
    extracting at least a second portion of the recirculated low oxygen content gas flow using an extraction conduit that is fluidly connected to the turbine compressor.
  12. A method for controlling at least one master train of a stoichiometric exhaust gas recirculation power plant arrangement, comprising the steps of:
    compressing ambient air into a compressed ambient gas flow with at least one main air compressor;
    delivering at least a first portion of the compressed ambient gas flow, with a master compressed ambient gas flow rate, to a master turbine combustor that is fluidly connected to the at least one main air compressor;
    delivering a master fuel stream, having a master fuel stream flow rate, to the master turbine combustor for mixing with the at least a first portion of the compressed ambient gas flow and with at least a first portion of a master recirculated low oxygen content gas flow to form a master combustible mixture;
    burning the master combustible mixture in the master turbine combustor and thereby forming the master recirculated low oxygen content gas flow and driving a master turbine connected to a master turbine compressor via a master turbine shaft;
    recirculating the at least a first portion of the master recirculated low oxygen content gas flow from the master turbine to the master turbine compressor using a master recirculation loop;
    adjusting the master compressed ambient gas flow rate and adjusting the master fuel stream flow rate to achieve substantially stoichiometric combustion;
    venting an excess portion, if any, of the at least a first portion of the compressed ambient gas flow; and
    extracting at least a second portion of the master recirculated low oxygen content gas flow using a master extraction conduit that is fluidly connected to the master turbine compressor.
  13. The method of claim 12, further comprising controlling at least one slave train of a stoichiometric exhaust gas recirculation power plant arrangement, comprising the steps of:
    opening a slave air injection valve that fluidly connects the inter-train conduit to a slave turbine combustor;
    delivering at least a second portion of the compressed ambient gas flow, with a slave compressed ambient gas flow rate, to a slave turbine combustor that is fluidly connected to the at least one main air compressor;
    delivering a slave fuel stream, having a slave fuel stream flow rate, to the slave turbine combustor for mixing with the at least a second portion of the compressed ambient gas flow and with at least a first portion of a slave recirculated low oxygen content gas flow to form a slave combustible mixture;
    burning the slave combustible mixture in the slave turbine combustor and thereby forming the slave recirculated low oxygen content gas flow and driving a slave turbine connected to a slave turbine compressor via a slave turbine shaft;
    recirculating the at least a first portion of the slave recirculated low oxygen content gas flow from the slave turbine to the slave turbine compressor using a slave recirculation loop;
    adjusting the slave compressed ambient gas flow rate and adjusting the slave fuel stream flow rate to achieve substantially stoichiometric combustion;
    venting an excess portion, if any, of the at least a second portion of the compressed ambient gas flow; and
    extracting at least a second portion of the slave recirculated low oxygen content gas flow using a slave extraction conduit that is fluidly connected to the slave turbine compressor.
EP12180616.0A 2011-08-25 2012-08-16 Method for controlling a power plant Active EP2562366B1 (en)

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
US13/217,630 US9127598B2 (en) 2011-08-25 2011-08-25 Control method for stoichiometric exhaust gas recirculation power plant

Publications (3)

Publication Number Publication Date
EP2562366A2 true EP2562366A2 (en) 2013-02-27
EP2562366A3 EP2562366A3 (en) 2018-06-20
EP2562366B1 EP2562366B1 (en) 2020-11-18

Family

ID=45525315

Family Applications (1)

Application Number Title Priority Date Filing Date
EP12180616.0A Active EP2562366B1 (en) 2011-08-25 2012-08-16 Method for controlling a power plant

Country Status (3)

Country Link
US (1) US9127598B2 (en)
EP (1) EP2562366B1 (en)
CN (1) CN102953834B (en)

Cited By (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP3070299A1 (en) * 2015-03-19 2016-09-21 General Electric Company Power generation system having compressor creating excess air flow and supplemental compressor therefor
US9822670B2 (en) 2015-03-19 2017-11-21 General Electric Company Power generation system having compressor creating excess air flow and turbo-expander for cooling inlet air
US9828887B2 (en) 2015-03-19 2017-11-28 General Electric Company Power generation system having compressor creating excess air flow and turbo-expander to increase turbine exhaust gas mass flow
US9863284B2 (en) 2015-03-19 2018-01-09 General Electric Company Power generation system having compressor creating excess air flow and cooling fluid injection therefor

Families Citing this family (71)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN104098070B (en) 2008-03-28 2016-04-13 埃克森美孚上游研究公司 Low emission power generation and hydrocarbon recovery system and method
CN101981272B (en) 2008-03-28 2014-06-11 埃克森美孚上游研究公司 Low emission power generation and hydrocarbon recovery systems and methods
EA026915B1 (en) 2008-10-14 2017-05-31 Эксонмобил Апстрим Рисерч Компани Methods and systems for controlling the products of combustion
JP5920727B2 (en) 2009-11-12 2016-05-18 エクソンモービル アップストリーム リサーチ カンパニー Low emission power generation and hydrocarbon recovery system and method
MY165945A (en) 2010-07-02 2018-05-18 Exxonmobil Upstream Res Co Low emission power generation systems and methods
AU2011271633B2 (en) 2010-07-02 2015-06-11 Exxonmobil Upstream Research Company Low emission triple-cycle power generation systems and methods
AU2011271635B2 (en) 2010-07-02 2015-10-08 Exxonmobil Upstream Research Company Stoichiometric combustion of enriched air with exhaust gas recirculation
PL2588727T3 (en) 2010-07-02 2019-05-31 Exxonmobil Upstream Res Co Stoichiometric combustion with exhaust gas recirculation and direct contact cooler
TWI593872B (en) 2011-03-22 2017-08-01 艾克頌美孚上游研究公司 Integrated system and methods of generating power
TWI564474B (en) 2011-03-22 2017-01-01 艾克頌美孚上游研究公司 Integrated systems for controlling stoichiometric combustion in turbine systems and methods of generating power using the same
TWI563166B (en) 2011-03-22 2016-12-21 Exxonmobil Upstream Res Co Integrated generation systems and methods for generating power
TWI563165B (en) 2011-03-22 2016-12-21 Exxonmobil Upstream Res Co Power generation system and method for generating power
US9127598B2 (en) 2011-08-25 2015-09-08 General Electric Company Control method for stoichiometric exhaust gas recirculation power plant
US8713947B2 (en) * 2011-08-25 2014-05-06 General Electric Company Power plant with gas separation system
EP2578839A1 (en) * 2011-10-06 2013-04-10 Alstom Technology Ltd Method for the operation of a gas turbine with flue gas recirculation and corresponding apparatus
US9810050B2 (en) 2011-12-20 2017-11-07 Exxonmobil Upstream Research Company Enhanced coal-bed methane production
US20130269358A1 (en) * 2012-04-12 2013-10-17 General Electric Company Methods, systems and apparatus relating to reheat combustion turbine engines with exhaust gas recirculation
US20130269357A1 (en) * 2012-04-12 2013-10-17 General Electric Company Method and system for controlling a secondary flow system
US8539749B1 (en) * 2012-04-12 2013-09-24 General Electric Company Systems and apparatus relating to reheat combustion turbine engines with exhaust gas recirculation
US9353682B2 (en) * 2012-04-12 2016-05-31 General Electric Company Methods, systems and apparatus relating to combustion turbine power plants with exhaust gas recirculation
US9784185B2 (en) 2012-04-26 2017-10-10 General Electric Company System and method for cooling a gas turbine with an exhaust gas provided by the gas turbine
US10273880B2 (en) 2012-04-26 2019-04-30 General Electric Company System and method of recirculating exhaust gas for use in a plurality of flow paths in a gas turbine engine
US9869279B2 (en) 2012-11-02 2018-01-16 General Electric Company System and method for a multi-wall turbine combustor
US10215412B2 (en) * 2012-11-02 2019-02-26 General Electric Company System and method for load control with diffusion combustion in a stoichiometric exhaust gas recirculation gas turbine system
US9599070B2 (en) 2012-11-02 2017-03-21 General Electric Company System and method for oxidant compression in a stoichiometric exhaust gas recirculation gas turbine system
US9708977B2 (en) 2012-12-28 2017-07-18 General Electric Company System and method for reheat in gas turbine with exhaust gas recirculation
US9631815B2 (en) 2012-12-28 2017-04-25 General Electric Company System and method for a turbine combustor
US10107495B2 (en) 2012-11-02 2018-10-23 General Electric Company Gas turbine combustor control system for stoichiometric combustion in the presence of a diluent
US10161312B2 (en) 2012-11-02 2018-12-25 General Electric Company System and method for diffusion combustion with fuel-diluent mixing in a stoichiometric exhaust gas recirculation gas turbine system
US9611756B2 (en) 2012-11-02 2017-04-04 General Electric Company System and method for protecting components in a gas turbine engine with exhaust gas recirculation
US9574496B2 (en) 2012-12-28 2017-02-21 General Electric Company System and method for a turbine combustor
US9803865B2 (en) 2012-12-28 2017-10-31 General Electric Company System and method for a turbine combustor
US20140150402A1 (en) * 2012-11-30 2014-06-05 General Electric Company System and method for burning vanadium-containing fuels
US10208677B2 (en) 2012-12-31 2019-02-19 General Electric Company Gas turbine load control system
US9581081B2 (en) 2013-01-13 2017-02-28 General Electric Company System and method for protecting components in a gas turbine engine with exhaust gas recirculation
US9512759B2 (en) 2013-02-06 2016-12-06 General Electric Company System and method for catalyst heat utilization for gas turbine with exhaust gas recirculation
TW201502356A (en) 2013-02-21 2015-01-16 Exxonmobil Upstream Res Co Reducing oxygen in a gas turbine exhaust
US9938861B2 (en) 2013-02-21 2018-04-10 Exxonmobil Upstream Research Company Fuel combusting method
RU2637609C2 (en) 2013-02-28 2017-12-05 Эксонмобил Апстрим Рисерч Компани System and method for turbine combustion chamber
TW201500635A (en) 2013-03-08 2015-01-01 Exxonmobil Upstream Res Co Processing exhaust for use in enhanced oil recovery
US20140250945A1 (en) 2013-03-08 2014-09-11 Richard A. Huntington Carbon Dioxide Recovery
US9618261B2 (en) 2013-03-08 2017-04-11 Exxonmobil Upstream Research Company Power generation and LNG production
CN105008499A (en) 2013-03-08 2015-10-28 埃克森美孚上游研究公司 Power generation and methane recovery from methane hydrates
TWI654368B (en) * 2013-06-28 2019-03-21 美商艾克頌美孚上游研究公司 System, method and media for controlling exhaust gas flow in an exhaust gas recirculation gas turbine system
US9631542B2 (en) 2013-06-28 2017-04-25 General Electric Company System and method for exhausting combustion gases from gas turbine engines
US9835089B2 (en) 2013-06-28 2017-12-05 General Electric Company System and method for a fuel nozzle
US9617914B2 (en) 2013-06-28 2017-04-11 General Electric Company Systems and methods for monitoring gas turbine systems having exhaust gas recirculation
US9587510B2 (en) 2013-07-30 2017-03-07 General Electric Company System and method for a gas turbine engine sensor
US9903588B2 (en) 2013-07-30 2018-02-27 General Electric Company System and method for barrier in passage of combustor of gas turbine engine with exhaust gas recirculation
US9951658B2 (en) 2013-07-31 2018-04-24 General Electric Company System and method for an oxidant heating system
US10030588B2 (en) 2013-12-04 2018-07-24 General Electric Company Gas turbine combustor diagnostic system and method
US9752458B2 (en) 2013-12-04 2017-09-05 General Electric Company System and method for a gas turbine engine
US10227920B2 (en) 2014-01-15 2019-03-12 General Electric Company Gas turbine oxidant separation system
US9915200B2 (en) 2014-01-21 2018-03-13 General Electric Company System and method for controlling the combustion process in a gas turbine operating with exhaust gas recirculation
US9863267B2 (en) 2014-01-21 2018-01-09 General Electric Company System and method of control for a gas turbine engine
US10079564B2 (en) 2014-01-27 2018-09-18 General Electric Company System and method for a stoichiometric exhaust gas recirculation gas turbine system
US10047633B2 (en) 2014-05-16 2018-08-14 General Electric Company Bearing housing
US9885290B2 (en) 2014-06-30 2018-02-06 General Electric Company Erosion suppression system and method in an exhaust gas recirculation gas turbine system
US10060359B2 (en) 2014-06-30 2018-08-28 General Electric Company Method and system for combustion control for gas turbine system with exhaust gas recirculation
US10655542B2 (en) 2014-06-30 2020-05-19 General Electric Company Method and system for startup of gas turbine system drive trains with exhaust gas recirculation
US9819292B2 (en) 2014-12-31 2017-11-14 General Electric Company Systems and methods to respond to grid overfrequency events for a stoichiometric exhaust recirculation gas turbine
US9869247B2 (en) 2014-12-31 2018-01-16 General Electric Company Systems and methods of estimating a combustion equivalence ratio in a gas turbine with exhaust gas recirculation
US10788212B2 (en) 2015-01-12 2020-09-29 General Electric Company System and method for an oxidant passageway in a gas turbine system with exhaust gas recirculation
US10094566B2 (en) 2015-02-04 2018-10-09 General Electric Company Systems and methods for high volumetric oxidant flow in gas turbine engine with exhaust gas recirculation
US10316746B2 (en) 2015-02-04 2019-06-11 General Electric Company Turbine system with exhaust gas recirculation, separation and extraction
US10253690B2 (en) 2015-02-04 2019-04-09 General Electric Company Turbine system with exhaust gas recirculation, separation and extraction
US10267270B2 (en) 2015-02-06 2019-04-23 General Electric Company Systems and methods for carbon black production with a gas turbine engine having exhaust gas recirculation
US10145269B2 (en) 2015-03-04 2018-12-04 General Electric Company System and method for cooling discharge flow
US10480792B2 (en) 2015-03-06 2019-11-19 General Electric Company Fuel staging in a gas turbine engine
US10787963B2 (en) * 2015-05-14 2020-09-29 University Of Central Florida Research Foundation, Inc. Compressor flow extraction apparatus and methods for supercritical CO2 oxy-combustion power generation system
US11815023B2 (en) * 2021-10-22 2023-11-14 Hamilton Sundstrand Corporation Power and ejector cooling unit

Family Cites Families (106)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US2621475A (en) 1946-06-13 1952-12-16 Phillips Petroleum Co Operation of multistage combustion gas turbines
US2646663A (en) * 1949-08-31 1953-07-28 Rateau Soc Semiopen circuit gas-turbine engine
DE1751851B2 (en) 1968-08-08 1973-12-13 Motoren- Und Turbinen-Union Muenchen Gmbh, 8000 Muenchen Gas turbine plant
US3685287A (en) 1970-12-08 1972-08-22 Mcculloch Corp Re-entry type integrated gas turbine engine and method of operation
US3771969A (en) 1971-05-10 1973-11-13 Arvin Ind Inc Catalytic converter
US3875380A (en) 1971-12-06 1975-04-01 Westinghouse Electric Corp Industrial gas turbine power plant control system and method implementing improved dual fuel scheduling algorithm permitting automatic fuel transfer under load
SE375583B (en) 1973-05-22 1975-04-21 United Turbine Ab & Co
US3866411A (en) 1973-12-27 1975-02-18 Texaco Inc Gas turbine process utilizing purified fuel and recirculated flue gases
US3949548A (en) 1974-06-13 1976-04-13 Lockwood Jr Hanford N Gas turbine regeneration system
US4271664A (en) * 1977-07-21 1981-06-09 Hydragon Corporation Turbine engine with exhaust gas recirculation
US4267692A (en) 1979-05-07 1981-05-19 Hydragon Corporation Combined gas turbine-rankine turbine power plant
US4313300A (en) 1980-01-21 1982-02-02 General Electric Company NOx reduction in a combined gas-steam power plant
US4330038A (en) 1980-05-14 1982-05-18 Zimpro-Aec Ltd. Oil reclamation process
JPS5781126A (en) * 1980-11-07 1982-05-21 Ishikawajima Harima Heavy Ind Co Ltd Gas turbine system and rotating speed control method for gas turbine
JPS5781125A (en) 1980-11-10 1982-05-21 Mitsubishi Heavy Ind Ltd Integrated rotation measuring device for engine
US4434613A (en) 1981-09-02 1984-03-06 General Electric Company Closed cycle gas turbine for gaseous production
US4492085A (en) 1982-08-09 1985-01-08 General Electric Company Gas turbine power plant
US4530207A (en) * 1983-05-05 1985-07-23 Asea-Stal Ab Power plant with a fluidized bed combustion chamber
US4528811A (en) 1983-06-03 1985-07-16 General Electric Co. Closed-cycle gas turbine chemical processor
DE3320228A1 (en) 1983-06-03 1984-12-06 Kraftwerk Union AG, 4330 Mülheim POWER PLANT WITH AN INTEGRATED COAL GASIFICATION PLANT
US4533314A (en) 1983-11-03 1985-08-06 General Electric Company Method for reducing nitric oxide emissions from a gaseous fuel combustor
US4561245A (en) 1983-11-14 1985-12-31 Atlantic Richfield Company Turbine anti-icing system
US5177954A (en) 1984-10-10 1993-01-12 Paul Marius A Gas turbine engine with cooled turbine blades
US4622808A (en) * 1984-12-20 1986-11-18 United Technologies Corporation Surge/stall cessation detection system
JPH0663646B2 (en) * 1985-10-11 1994-08-22 株式会社日立製作所 Combustor for gas turbine
JPH0337333A (en) 1989-07-05 1991-02-18 Mitsubishi Heavy Ind Ltd Power generator utilizing compressed air
CH681480A5 (en) 1990-06-07 1993-03-31 Asea Brown Boveri
CH684963A5 (en) 1991-11-13 1995-02-15 Asea Brown Boveri Annular combustion chamber.
JP3209775B2 (en) 1992-01-10 2001-09-17 株式会社日立製作所 Combined cycle power plant and its operation method
DE4223828A1 (en) 1992-05-27 1993-12-02 Asea Brown Boveri Method for operating a combustion chamber of a gas turbine
US6289666B1 (en) 1992-10-27 2001-09-18 Ginter Vast Corporation High efficiency low pollution hybrid Brayton cycle combustor
US5794431A (en) 1993-07-14 1998-08-18 Hitachi, Ltd. Exhaust recirculation type combined plant
DE4331081A1 (en) 1993-09-13 1995-03-16 Abb Management Ag Process for operating a gas turbine plant
DE4411624A1 (en) 1994-04-02 1995-10-05 Abb Management Ag Combustion chamber with premix burners
DE4435322B4 (en) 1994-10-01 2005-05-04 Alstom Method and device for shaft seal and for cooling on the exhaust side of an axial flowed gas turbine
DE19502796B4 (en) 1995-01-30 2004-10-28 Alstom burner
US5595059A (en) 1995-03-02 1997-01-21 Westingthouse Electric Corporation Combined cycle power plant with thermochemical recuperation and flue gas recirculation
US5724805A (en) 1995-08-21 1998-03-10 University Of Massachusetts-Lowell Power plant with carbon dioxide capture and zero pollutant emissions
US6105362A (en) * 1995-09-22 2000-08-22 Kabushiki Kaisha Toshiba Combined cycle power plant with gas turbine cooling system
US5822992A (en) 1995-10-19 1998-10-20 General Electric Company Low emissions combustor premixer
US5809768A (en) 1997-04-08 1998-09-22 Mitsubishi Heavy Industries, Ltd. Hydrogen-oxygen combustion turbine plant
US6256976B1 (en) 1997-06-27 2001-07-10 Hitachi, Ltd. Exhaust gas recirculation type combined plant
US6050082A (en) 1998-01-20 2000-04-18 General Electric Company Intercooled gas turbine engine with integral air bottoming cycle
EP0939199B1 (en) 1998-02-25 2004-03-31 ALSTOM Technology Ltd Power plant and process for operating a power plant with a CO2-cycle
EP0953748B1 (en) 1998-04-28 2004-01-28 ALSTOM (Switzerland) Ltd Power plant with a CO2-cycle
US6082093A (en) 1998-05-27 2000-07-04 Solar Turbines Inc. Combustion air control system for a gas turbine engine
JP3783442B2 (en) 1999-01-08 2006-06-07 株式会社日立製作所 Control method of gas turbine
DE19944922A1 (en) * 1999-09-20 2001-03-22 Asea Brown Boveri Control of primary measures to reduce thermal nitrogen oxide formation in gas turbines
US6389793B1 (en) 2000-04-19 2002-05-21 General Electric Company Combustion turbine cooling media supply system and related method
AU2001276823A1 (en) 2000-05-12 2001-12-03 Clean Energy Systems, Inc. Semi-closed brayton cycle gas turbine power systems
US6430915B1 (en) * 2000-08-31 2002-08-13 Siemens Westinghouse Power Corporation Flow balanced gas turbine power plant
US6651421B2 (en) 2000-10-02 2003-11-25 Richard R. Coleman Coleman regenerative engine with exhaust gas water extraction
DE50208649D1 (en) 2001-04-06 2006-12-21 Alstom Technology Ltd PROCESS FOR MAINTAINING A KOMBIKRAFTWERKES
WO2002095852A2 (en) 2001-05-24 2002-11-28 Clean Energy Systems, Inc. Combined fuel cell and fuel combustion power generation systems
US20030221409A1 (en) 2002-05-29 2003-12-04 Mcgowan Thomas F. Pollution reduction fuel efficient combustion turbine
EP1448880A1 (en) 2001-09-24 2004-08-25 ALSTOM Technology Ltd Gas turbine system for working fluid in the form of a carbon dioxide/water mixture
US20040011057A1 (en) 2002-07-16 2004-01-22 Siemens Westinghouse Power Corporation Ultra-low emission power plant
DK1549881T3 (en) 2002-10-10 2016-05-17 Lpp Comb Llc Liquid fuel atomization system for combustion and method of use
WO2004072443A1 (en) 2003-02-11 2004-08-26 Statoil Asa Efficient combined cycle power plant with co2 capture and a combustor arrangement with separate flows
GB2401403B (en) 2003-05-08 2006-05-31 Rolls Royce Plc Carbon dioxide recirculation
DE10325111A1 (en) 2003-06-02 2005-01-05 Alstom Technology Ltd Method for generating energy in a gas turbine comprehensive power generation plant and power plant for performing the method
US7007487B2 (en) 2003-07-31 2006-03-07 Mes International, Inc. Recuperated gas turbine engine system and method employing catalytic combustion
US7107774B2 (en) 2003-08-12 2006-09-19 Washington Group International, Inc. Method and apparatus for combined cycle power plant operation
US7032388B2 (en) 2003-11-17 2006-04-25 General Electric Company Method and system for incorporating an emission sensor into a gas turbine controller
DE10360951A1 (en) 2003-12-23 2005-07-28 Alstom Technology Ltd Thermal power plant with sequential combustion and reduced CO2 emissions and method of operating such a plant
US7124591B2 (en) 2004-01-09 2006-10-24 Siemens Power Generation, Inc. Method for operating a gas turbine
US20080193886A1 (en) 2004-02-10 2008-08-14 Ebara Corporation Combustion Apparatus
US20090078587A1 (en) 2004-06-18 2009-03-26 Bjr Sensors, Llc Method of Sensor Conditioning for Improving Signal Output Stability for Mixed Gas Measurements
DE102004039164A1 (en) 2004-08-11 2006-03-02 Alstom Technology Ltd Method for generating energy in a gas turbine comprehensive power generation plant and power generation plant for performing the method
JP2006118391A (en) * 2004-10-20 2006-05-11 Mitsubishi Heavy Ind Ltd Control device for extracted air boosting facility in integrated gasification combined cycle plant
US7383686B2 (en) 2004-12-13 2008-06-10 Honeywell International Inc. Secondary flow, high pressure turbine module cooling air system for recuperated gas turbine engines
DE102005015151A1 (en) 2005-03-31 2006-10-26 Alstom Technology Ltd. Gas turbine system for power station, has control device to control volume flow and/or temperature of combustion exhaust gas, such that fresh gas-exhaust gas-mixture entering into compressor of turbo group has preset reference temperature
US7266940B2 (en) 2005-07-08 2007-09-11 General Electric Company Systems and methods for power generation with carbon dioxide isolation
FR2891013B1 (en) 2005-09-16 2011-01-14 Inst Francais Du Petrole GENERATION OF ENERGY BY GAS TURBINE WITHOUT C02 EMISSION
US7523602B2 (en) 2005-09-27 2009-04-28 United Technologies Corporation Turbine exhaust catalyst
US7726114B2 (en) 2005-12-07 2010-06-01 General Electric Company Integrated combustor-heat exchanger and systems for power generation using the same
US7784288B2 (en) 2006-03-06 2010-08-31 General Electric Company Methods and systems of variable extraction for compressor protection
US7650744B2 (en) 2006-03-24 2010-01-26 General Electric Company Systems and methods of reducing NOx emissions in gas turbine systems and internal combustion engines
US7739864B2 (en) * 2006-11-07 2010-06-22 General Electric Company Systems and methods for power generation with carbon dioxide isolation
US7895822B2 (en) 2006-11-07 2011-03-01 General Electric Company Systems and methods for power generation with carbon dioxide isolation
US8850789B2 (en) 2007-06-13 2014-10-07 General Electric Company Systems and methods for power generation with exhaust gas recirculation
JP5366941B2 (en) 2007-06-19 2013-12-11 アルストム テクノロジー リミテッド Exhaust gas recirculation gas turbine equipment
US9404418B2 (en) 2007-09-28 2016-08-02 General Electric Company Low emission turbine system and method
EP2078827A1 (en) 2008-01-11 2009-07-15 ALSTOM Technology Ltd Power plant with CO2 capture and compression
US20090280003A1 (en) 2008-05-08 2009-11-12 Jesse Jay Schriner Method and system for monitoring particulate
US8397482B2 (en) 2008-05-15 2013-03-19 General Electric Company Dry 3-way catalytic reduction of gas turbine NOx
US20090301054A1 (en) 2008-06-04 2009-12-10 Simpson Stanley F Turbine system having exhaust gas recirculation and reheat
US20100018218A1 (en) 2008-07-25 2010-01-28 Riley Horace E Power plant with emissions recovery
US8015822B2 (en) 2008-11-21 2011-09-13 General Electric Company Method for controlling an exhaust gas recirculation system
US20100170218A1 (en) 2009-01-05 2010-07-08 General Electric Company Method for expanding compressor discharge bleed air
US20100175386A1 (en) 2009-01-09 2010-07-15 General Electric Company Premixed partial oxidation syngas generation and gas turbine system
US8172521B2 (en) 2009-01-15 2012-05-08 General Electric Company Compressor clearance control system using turbine exhaust
US20100180565A1 (en) 2009-01-16 2010-07-22 General Electric Company Methods for increasing carbon dioxide content in gas turbine exhaust and systems for achieving the same
US8151571B2 (en) 2009-09-18 2012-04-10 General Electric Company Systems and methods for closed loop emissions control
US20110138766A1 (en) 2009-12-15 2011-06-16 General Electric Company System and method of improving emission performance of a gas turbine
US7980052B1 (en) * 2010-05-20 2011-07-19 Florida Turbine Technologies, Inc. Industrial gas turbine engine
CH703218A1 (en) 2010-05-26 2011-11-30 Alstom Technology Ltd Method of operating a combined cycle with flue gas recirculation and power plant.
US8453462B2 (en) * 2011-08-25 2013-06-04 General Electric Company Method of operating a stoichiometric exhaust gas recirculation power plant
US8245493B2 (en) * 2011-08-25 2012-08-21 General Electric Company Power plant and control method
US8266913B2 (en) * 2011-08-25 2012-09-18 General Electric Company Power plant and method of use
US9127598B2 (en) 2011-08-25 2015-09-08 General Electric Company Control method for stoichiometric exhaust gas recirculation power plant
US8245492B2 (en) * 2011-08-25 2012-08-21 General Electric Company Power plant and method of operation
US8205455B2 (en) 2011-08-25 2012-06-26 General Electric Company Power plant and method of operation
US8266883B2 (en) * 2011-08-25 2012-09-18 General Electric Company Power plant start-up method and method of venting the power plant
US8347600B2 (en) * 2011-08-25 2013-01-08 General Electric Company Power plant and method of operation
US8453461B2 (en) * 2011-08-25 2013-06-04 General Electric Company Power plant and method of operation

Non-Patent Citations (1)

* Cited by examiner, † Cited by third party
Title
None

Cited By (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP3070299A1 (en) * 2015-03-19 2016-09-21 General Electric Company Power generation system having compressor creating excess air flow and supplemental compressor therefor
US9822670B2 (en) 2015-03-19 2017-11-21 General Electric Company Power generation system having compressor creating excess air flow and turbo-expander for cooling inlet air
US9828887B2 (en) 2015-03-19 2017-11-28 General Electric Company Power generation system having compressor creating excess air flow and turbo-expander to increase turbine exhaust gas mass flow
US9863284B2 (en) 2015-03-19 2018-01-09 General Electric Company Power generation system having compressor creating excess air flow and cooling fluid injection therefor

Also Published As

Publication number Publication date
EP2562366A3 (en) 2018-06-20
CN102953834B (en) 2016-04-20
US9127598B2 (en) 2015-09-08
CN102953834A (en) 2013-03-06
EP2562366B1 (en) 2020-11-18
US20120023958A1 (en) 2012-02-02

Similar Documents

Publication Publication Date Title
EP2562366B1 (en) Method for controlling a power plant
US8453462B2 (en) Method of operating a stoichiometric exhaust gas recirculation power plant
US8347600B2 (en) Power plant and method of operation
EP2562389B1 (en) Method of operating a power plant with exhaust gas recirculation
US8713947B2 (en) Power plant with gas separation system
EP2562391B1 (en) Gas turbine power plant arrangement and controll method
EP2562385B1 (en) Power plant and method of operation
EP2562388A2 (en) Power plant and method of operation
US8266913B2 (en) Power plant and method of use
US8266883B2 (en) Power plant start-up method and method of venting the power plant
US8205455B2 (en) Power plant and method of operation
JP6662638B2 (en) Gas turbine load control system
US20130269355A1 (en) Method and system for controlling an extraction pressure and temperature of a stoichiometric egr system
US8813472B2 (en) System and method for controlling a semi-closed power cycle system

Legal Events

Date Code Title Description
PUAI Public reference made under article 153(3) epc to a published international application that has entered the european phase

Free format text: ORIGINAL CODE: 0009012

AK Designated contracting states

Kind code of ref document: A2

Designated state(s): AL AT BE BG CH CY CZ DE DK EE ES FI FR GB GR HR HU IE IS IT LI LT LU LV MC MK MT NL NO PL PT RO RS SE SI SK SM TR

AX Request for extension of the european patent

Extension state: BA ME

PUAL Search report despatched

Free format text: ORIGINAL CODE: 0009013

AK Designated contracting states

Kind code of ref document: A3

Designated state(s): AL AT BE BG CH CY CZ DE DK EE ES FI FR GB GR HR HU IE IS IT LI LT LU LV MC MK MT NL NO PL PT RO RS SE SI SK SM TR

AX Request for extension of the european patent

Extension state: BA ME

RIC1 Information provided on ipc code assigned before grant

Ipc: F01D 13/02 20060101AFI20180515BHEP

Ipc: F02C 3/34 20060101ALI20180515BHEP

STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: REQUEST FOR EXAMINATION WAS MADE

17P Request for examination filed

Effective date: 20181220

RBV Designated contracting states (corrected)

Designated state(s): AL AT BE BG CH CY CZ DE DK EE ES FI FR GB GR HR HU IE IS IT LI LT LU LV MC MK MT NL NO PL PT RO RS SE SI SK SM TR

GRAP Despatch of communication of intention to grant a patent

Free format text: ORIGINAL CODE: EPIDOSNIGR1

STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: GRANT OF PATENT IS INTENDED

INTG Intention to grant announced

Effective date: 20191009

GRAJ Information related to disapproval of communication of intention to grant by the applicant or resumption of examination proceedings by the epo deleted

Free format text: ORIGINAL CODE: EPIDOSDIGR1

STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: REQUEST FOR EXAMINATION WAS MADE

GRAP Despatch of communication of intention to grant a patent

Free format text: ORIGINAL CODE: EPIDOSNIGR1

INTC Intention to grant announced (deleted)
STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: GRANT OF PATENT IS INTENDED

INTG Intention to grant announced

Effective date: 20200319

GRAJ Information related to disapproval of communication of intention to grant by the applicant or resumption of examination proceedings by the epo deleted

Free format text: ORIGINAL CODE: EPIDOSDIGR1

STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: REQUEST FOR EXAMINATION WAS MADE

GRAP Despatch of communication of intention to grant a patent

Free format text: ORIGINAL CODE: EPIDOSNIGR1

STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: GRANT OF PATENT IS INTENDED

INTC Intention to grant announced (deleted)
INTG Intention to grant announced

Effective date: 20200622

GRAS Grant fee paid

Free format text: ORIGINAL CODE: EPIDOSNIGR3

GRAA (expected) grant

Free format text: ORIGINAL CODE: 0009210

STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: THE PATENT HAS BEEN GRANTED

AK Designated contracting states

Kind code of ref document: B1

Designated state(s): AL AT BE BG CH CY CZ DE DK EE ES FI FR GB GR HR HU IE IS IT LI LT LU LV MC MK MT NL NO PL PT RO RS SE SI SK SM TR

REG Reference to a national code

Ref country code: GB

Ref legal event code: FG4D

REG Reference to a national code

Ref country code: CH

Ref legal event code: EP

REG Reference to a national code

Ref country code: IE

Ref legal event code: FG4D

REG Reference to a national code

Ref country code: DE

Ref legal event code: R096

Ref document number: 602012073260

Country of ref document: DE

REG Reference to a national code

Ref country code: AT

Ref legal event code: REF

Ref document number: 1336003

Country of ref document: AT

Kind code of ref document: T

Effective date: 20201215

REG Reference to a national code

Ref country code: AT

Ref legal event code: MK05

Ref document number: 1336003

Country of ref document: AT

Kind code of ref document: T

Effective date: 20201118

REG Reference to a national code

Ref country code: NL

Ref legal event code: MP

Effective date: 20201118

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: PT

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20210318

Ref country code: NO

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20210218

Ref country code: RS

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20201118

Ref country code: FI

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20201118

Ref country code: GR

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20210219

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: PL

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20201118

Ref country code: LV

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20201118

Ref country code: SE

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20201118

Ref country code: IS

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20210318

Ref country code: AT

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20201118

Ref country code: BG

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20210218

REG Reference to a national code

Ref country code: LT

Ref legal event code: MG9D

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: HR

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20201118

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: SM

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20201118

Ref country code: EE

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20201118

Ref country code: CZ

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20201118

Ref country code: LT

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20201118

Ref country code: SK

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20201118

Ref country code: RO

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20201118

REG Reference to a national code

Ref country code: DE

Ref legal event code: R097

Ref document number: 602012073260

Country of ref document: DE

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: DK

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20201118

PLBE No opposition filed within time limit

Free format text: ORIGINAL CODE: 0009261

STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: NO OPPOSITION FILED WITHIN TIME LIMIT

26N No opposition filed

Effective date: 20210819

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: NL

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20201118

Ref country code: AL

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20201118

Ref country code: IT

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20201118

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: SI

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20201118

Ref country code: ES

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20201118

REG Reference to a national code

Ref country code: CH

Ref legal event code: PL

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: MC

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20201118

REG Reference to a national code

Ref country code: BE

Ref legal event code: MM

Effective date: 20210831

GBPC Gb: european patent ceased through non-payment of renewal fee

Effective date: 20210816

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: LI

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20210831

Ref country code: CH

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20210831

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: IS

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20210318

Ref country code: LU

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20210816

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: IE

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20210816

Ref country code: GB

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20210816

Ref country code: FR

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20210831

Ref country code: BE

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20210831

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: HU

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT; INVALID AB INITIO

Effective date: 20120816

Ref country code: CY

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20201118

REG Reference to a national code

Ref country code: DE

Ref legal event code: R081

Ref document number: 602012073260

Country of ref document: DE

Owner name: GENERAL ELECTRIC TECHNOLOGY GMBH, CH

Free format text: FORMER OWNER: GENERAL ELECTRIC COMPANY, SCHENECTADY, NY, US

PGFP Annual fee paid to national office [announced via postgrant information from national office to epo]

Ref country code: DE

Payment date: 20230720

Year of fee payment: 12